NRG 10-K Fiscal year ended Dec. 31, 2024

Portions of the Registrant's definitive Proxy Statement relating to its 2025 Annual Meeting of Stockholders

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The Company leverages a comprehensive, multi-tiered cybersecurity strategy to manage cybersecurity risk based on criteria established by the NIST Cybersecurity Framework. As part of its cybersecurity strategy, the Company utilizes a range of industry and regulatory standards including, but not limited to, NERC-CIP, Payment Card Industry Data Security Standard, and IoT Security Assurance Framework. Compliance with NERC-CIP standards is mandated for entities involved in power generation, transmission, and distribution by regulatory bodies responsible for protecting critical infrastructure within the United States. NRG engages certified external assessors to ensure compliance with these standards.

The Company’s strategy seeks to align underlying processes not only with industry standards but also mirror best practices among peer organizations. The strategy ensures a standardized method across all activities at NRG allowing for consistent recognition, assessment and potential mitigation of significant cybersecurity risks. To further the strategy, the Company established the NRG Cybersecurity Integration Center ("CIC") which is composed of experienced team members from across cybersecurity disciplines with relevant educational and industry experience. The CIC provides the following functions to the Company: cyber governance, operations, detection and response, engineering, testing, cyber risk management (including third-party risks), compliance, training and awareness, and reporting. The CIC utilizes advanced continuous monitoring systems and investigative techniques for real-time threat detection . The systematic monitoring approach allows for risk classification and prioritization based on potential impacts, and facilitates targeted resource allocation according to risk severity. The Company conducts regular penetration testing to proactively identify vulnerabilities and enhance its defense measures. The Company engages third-party assessors to gain comprehensive insights into its cyber risk profile.

The Chief Information Security Officer ("CISO") is the head of cybersecurity for the Company and leads the CIC. The CISO has decades of professional experience, education, and certification in security analysis, design, implementation, and management, with a particularly strong background in technical vulnerability assessment and program development. Within various roles throughout the CISO's career, he has overseen information assurance and cybersecurity efforts, including critical infrastructure protection in government agencies and industry.

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At least twice per year, the CISO provides comprehensive updates to the Board of Directors on cybersecurity and any recent developments impacting the Company. These updates include, among other items:

• Incident reports and developments from any cybersecurity events;

• Current cybersecurity landscape and emerging cybersecurity threats, with a particular emphasis on Company and industry-specific threats; and

• Status of ongoing initiatives to strengthen the Company's cybersecurity program.

In addition, the CISO regularly informs other members of senior management, including the President and CEO, of all aspects related to cybersecurity risks and incidents. This is intended to ensure that the highest levels of management remain updated on the cybersecurity risk preparedness and potential risks facing the Company. Furthermore, significant cybersecurity matters and strategic risk management decisions are escalated to the Board of Directors ensuring that they have comprehensive oversight and can provide guidance on critical cybersecurity issues.

The Board of Directors is primarily responsible for the risk oversight of the Company, and has delegated oversight of risks related to cybersecurity to the Finance and Risk Management ("FARM") Committee of the Board. The FARM Committee regularly reports on its activities to the Board of Directors after each meeting . The FARM Committee, as well as the overall Board of Directors, is composed of members with diverse expertise, including risk management, incident response and technology. The Board of Directors is aware of the critical nature of managing risks associated with cybersecurity threats and has worked with the Company’s management to establish comprehensive oversight mechanisms to ensure effective cybersecurity governance.

The FARM Committee and the Board of Directors receive updates on any significant developments in the cybersecurity domain, seeking to ensure that the Board of Director’s oversight is proactive and responsive. The Board of Directors remains involved in ensuring that cybersecurity considerations are integrated into the Company’s broader strategic objectives. Pursuant to the charter of the FARM Committee, the FARM Committee's responsibilities include an annual review of the Company’s cybersecurity program and the effectiveness of its risk management strategies. This review is intended to help identify areas for improvement and ensure the alignment of cybersecurity efforts with the overall risk management framework.

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(f) For further discussion of the Capped Call Options, see Item 15 — Note 15 , Capital Structure

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General

NRG Energy, Inc., or NRG or the Company, is a leading energy and smart home company fueled by market-leading brands, proprietary technologies, and complementary sales channels. Across the United States and Canada, NRG delivers innovative, sustainable solutions, predominately under the brand names such as NRG, Reliant, Direct Energy, Green Mountain Energy and Vivint, while also advocating for competitive energy markets and customer choice. The Company has a customer base that includes approximately 8 million residential customers (comprised of 6 million retail energy customers and 2 million smart home customers) in addition to commercial, industrial, and wholesale customers, supported by approximately 13 GW of generation as of December 31, 2024.

The Company's business is segmented as follows:

• Texas, which includes all activity related to customer, plant and market operations in Texas, other than Cottonwood;

• East, which includes all activity related to customer, plant and market operations in the East;

• West/Services/Other, which includes the following assets and activities: (i) all activity related to customer, plant and market operations in the West and Canada, and (ii) activity related to the Cottonwood facility and other investments;

• Vivint Smart Home; and

Basis of Presentation and Principles of Consolidation

The Company's consolidated financial statements have been prepared in accordance with U.S. GAAP. The ASC, established by the FASB, is the source of authoritative U.S. GAAP to be applied by nongovernmental entities. In addition, the rules and interpretative releases of the SEC under authority of federal securities laws are also sources of authoritative U.S. GAAP for SEC registrants.

The consolidated financial statements include NRG's accounts and operations and those of its subsidiaries in which the Company has a controlling interest. All significant intercompany transactions and balances have been eliminated in consolidation. The usual condition for a controlling financial interest is ownership of a majority of the voting interests of an entity. However, a controlling financial interest may also exist through arrangements that do not involve controlling voting interests. As such, NRG applies the guidance of ASC 810, Consolidations, or ASC 810, to determine when an entity that is insufficiently capitalized or not controlled through its voting interests, referred to as a VIE, should be consolidated.

Presentation Adjustments

Beginning in the third quarter of 2024, the Company is recording the amortization of capitalized contracts costs within depreciation and amortization. This change, along with additional financial statement disclosures, is meant to address investor inquiries by enhancing transparency to easier match expenses with revenues. NRG previously recorded amortization of capitalized contract costs related to fulfillment in cost of operations and amortization of capitalized contract costs related to customer acquisition primarily in selling, general and administrative costs in the consolidated statements of operations. Prior years amounts were adjusted for comparative purposes. The adjustments had no impact on the Company’s total operating costs and expenses, and total cash flows.

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The following table presents adjustments within the consolidated statement of operations for the years ended December 31, 2023 and 2022 related to capitalized contract costs:

(In millions)						As Previously Presented						Presentation Adjustments						As Adjusted
Year ended December 31, 2023
Cost of operations (excluding depreciation and amortization shown below)						$	26,526					$	( 43 )					$	26,483
Depreciation and amortization						1,127						168						1,295
Selling, general and administrative costs						1,968						( 125 )						1,843
Year ended December 31, 2022
Cost of operations (excluding depreciation and amortization shown below)						$	27,446					$	( 3 )					$	27,443
Depreciation and amortization						634						86						720
Selling, general and administrative costs						1,228						( 83 )						1,145

The following table presents adjustments within the consolidated statement of cash flows for the years ended December 31, 2023 and 2022 related to capitalized contract costs:

(In millions)						As Previously Presented						Presentation Adjustments						As Adjusted
Year ended December 31, 2023
Cash flows from operating activities:
Amortization of capitalized contract costs						$	—					$	168					$	168
Prepayments and other current assets						( 233 )						( 168 )						( 401 )
Year ended December 31, 2022
Cash flows from operating activities:
Amortization of capitalized contract costs						$	—					$	86					$	86
Prepayments and other current assets						17						( 86 )						( 69 )

Winter Storm Uri Uplift Securitization Proceeds

In May 2021, the Texas Legislature passed House Bill (“HB”) 4492 to mitigate exceptionally high price adders and ancillary service costs incurred by ERCOT LSEs during Winter Storm Uri. HB 4492 authorized ERCOT to obtain $2.1 billion of financing to distribute to LSEs that were charged and paid to ERCOT those highly priced ancillary service and online reliability deployment price adders during Winter Storm Uri.

In December 2021, ERCOT filed with the PUCT a calculation of each LSE’s share of proceeds based on the settlement methodology. The Company accounted for the proceeds by analogy to the contribution model within ASC 958-605, Not-for-Profit Entities- Revenue Recognition and the grant model within IAS 20, Accounting for Government Grants and Disclosure of Government Assistance , as a reduction to expenses in the consolidated statements of operations in the 2021 annual period for which the proceeds were intended to compensate. In June 2022, the Company received proceeds of $ 689 million from ERCOT in relation with HB 4492.

Credit Losses

In accordance with ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments , or ASU No. 2016-13, retail trade receivables are reported on the balance sheet net of the allowance for credit losses within accounts receivables, net. Long-term receivables are recorded net in other non-current assets on the consolidated balance sheet. The Company accrues an allowance for current expected credit losses based on (i) estimates of uncollectible revenues by analyzing accounts receivable aging and current and reasonable forecasts of expected economic factors including, but not limited to, unemployment rates and weather-related events, (ii) historical collections and delinquencies, and (iii) counterparty credit ratings for commercial and industrial customers. The Company writes off customer contract receivable balances against the allowance for credit losses when it is determined a receivable is uncollectible.

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The following table presents the activity in the allowance for credit losses for the years ended December 31, 2024, 2023, and 2022:

			Year Ended December 31,
(In millions)			2024						2023						2022
Beginning balance			$	145					$	133					$	683
Acquired balance from Vivint Smart Home			—						22						—
Provision for credit losses (a)			314						251						11
Write-offs			( 363 )						( 313 )						( 593 )
Recoveries collected			38						39						32
Other			18						13						—
Ending balance (a)			$	152					$	145					$	133

(a) Includes bilateral finance hedging risk of $( 70 ) million accounted for under ASC 815 for the year ended December 31, 2022

During the year ended December 31, 2022, the provision for credit losses included the Company's loss mitigation efforts recognized as income of $ 126 million related to Winter Storm Uri. The increase in write-offs during the year ended December 31, 2022 was primarily due to the resolution of credit losses that occurred during Winter Storm Uri.

Cash and Cash Equivalents

Cash and cash equivalents include highly liquid investments with an original maturity of three months or less at the time of purchase.

Funds Deposited by Counterparties

Funds deposited by counterparties consist of cash held by the Company as a result of collateral posting obligations from its counterparties related to NRG's hedging program. The increase in funds deposited by counterparties is driven by the increase in forward positions as a result of increases in natural gas and power prices compared to December 31, 2023. Though some amounts are segregated into separate accounts, not all funds are contractually restricted. Based on the Company's intention, these funds are not available for the payment of general corporate obligations; however, they are available for liquidity management. Depending on market fluctuations and the settlement of the underlying contracts, the Company will refund this collateral to the hedge counterparties pursuant to the terms and conditions of the underlying trades. Since collateral requirements fluctuate daily and the Company cannot predict if any collateral will be held for more than twelve months, the funds deposited by counterparties are classified as a current asset on the Company's balance sheet, with an offsetting liability for this cash collateral received within current liabilities.

Restricted Cash

The following table provides a reconciliation of cash and cash equivalents, restricted cash and funds deposited by counterparties reported within the consolidated balance sheets that sum to the total of the same such amounts shown in the statements of cash flows.

			Year Ended December 31,
(In millions)			2024						2023						2022
Cash and cash equivalents			$	966					$	541					$	430
Funds deposited by counterparties			199						84						1,708
Restricted cash			8						24						40
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows			$	1,173					$	649					$	2,178

Restricted cash consists primarily of funds held within the Company's projects that are restricted in their use.

Inventory

Inventory is valued at the lower of weighted average cost or market, and consists principally of natural gas, fuel oil, coal, spare parts and finished goods. The Company removes natural gas inventory as goods are delivered to customers and as they are used in the production of electricity or steam. The Company removes fuel oil and coal inventories as they are used in the production of electricity. The Company removes spare parts inventories when they are used for repairs, maintenance or capital projects. The Company expects to recover the natural gas, fuel oil, coal and spare parts costs in the ordinary course of business. Inventory is valued at the lower of cost or net realizable value with cost being determined on a first in first out basis for finished goods and weighted average cost method for all other inventories. The Company removes finished goods inventories as they are

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sold to customers. Inventories sold to customers as part of a smart home system are generally capitalized as contract costs. Sales of inventory are classified as an operating activity in the consolidated statements of cash flows.

Property, Plant and Equipment

Property, plant and equipment are stated at cost or, in the case of business acquisitions, acquisition date fair value; however, impairment adjustments are recorded whenever events or changes in circumstances indicate that their carrying values may not be recoverable. Significant additions or improvements extending asset lives are capitalized as incurred, while repairs and maintenance that do not improve or extend the life of the respective asset are charged to expense as incurred. Depreciation, other than nuclear fuel, is computed using the straight-line method, while nuclear fuel was amortized based on units of production over the estimated useful lives. Certain assets and their related accumulated depreciation amounts are adjusted for asset retirements and disposals with the resulting gain or loss included in cost of operations in the consolidated statements of operations. For further discussion, see Note 8, Property, Plant and Equipment .

Business Interruption Insurance

The Company carries insurance policies to cover insurable risks including, but not limited to, business interruption. There were no business interruption insurance settlements during the year ended December 31, 2024. As a result of damage at the Limestone 1 and W.A. Parish 8 units, the Company recorded business interruption insurance settlements of $ 7 million and $ 81 million during the years ended December 31, 2023 and 2022, respectively. Business interruption insurance is recorded to cost of operations in the consolidated statements of operations and cash provided by operating activities in the consolidated statement of cash flows.

Asset Impairments

Long-lived assets that are held and used are reviewed for impairment whenever events or changes in circumstances indicate carrying values may not be recoverable. Such reviews are performed in accordance with ASC 360. An impairment loss is indicated if the total future estimated undiscounted cash flows expected from an asset are less than its carrying value. An impairment charge is measured by the difference between an asset's carrying amount and fair value with the difference recorded in operating costs and expenses in the consolidated statements of operations. Fair values are determined by a variety of valuation methods, including third-party appraisals, sales prices of similar assets and present value techniques.

Investments accounted for by the equity method are reviewed for impairment in accordance with ASC 323, Investments-Equity Method and Joint Ventures , or ASC 323, which requires that a loss in value of an investment that is an other-than-temporary decline should be recognized. The Company identifies and measures losses in the value of equity method investments based upon a comparison of fair value to carrying value. For further discussion of these matters, refer to Note 10, Asset Impairments .

Debt Issuance Costs

Debt issuance costs are capitalized and amortized as interest expense on a basis that approximates the effective interest method over the term of the related debt. Debt issuance costs are presented as a direct deduction from the carrying amount of the related debt, or as an asset if the issuance costs relate to revolving debt agreements or certain other financing arrangements.

Intangible Assets

Intangible assets represent contractual rights held by the Company. The Company recognizes specifically identifiable intangible assets including emissions allowances, customer and supply contracts, customer relationships, marketing partnerships, technologies, trade names and fuel contracts when specific rights and contracts are acquired. These intangible assets are amortized based on expected volumes, expected delivery, expected discounted future net cash flows, straight line or units of production basis. As of December 31, 2024 and 2023, the Company had accumulated amortization related to its intangible assets of $ 3.6 billion and $ 3.0 billion, respectively.

Emission allowances held-for-sale, which are included in other non-current assets on the Company's consolidated balance sheet, are not amortized; they are carried at the lower of cost or fair value and reviewed for impairment in accordance with ASC 360.

For further discussion, see Note 11, Goodwill and Other Intangibles .

Goodwill

In accordance with ASC 350, Intangibles-Goodwill and Other , or ASC 350, the Company recognizes goodwill for the excess cost of an acquired entity over the net value assigned to assets acquired and liabilities assumed. NRG performs goodwill impairment tests annually, during the fourth quarter, and when events or changes in circumstances indicate that the carrying value may not be recoverable.

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The Company may first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The more-likely-than-not threshold is defined as having a likelihood of more than 50 percent. If it is not more-likely-than-not that the fair value of a reporting unit is less than its carrying amount, there is no goodwill impairment.

In the absence of sufficient qualitative factors indicating that it is more-likely-than-not that no impairment occurred, the Company performs a quantitative assessment by determining the fair value of the reporting unit and comparing the fair value to its book value. If the fair value of the reporting unit exceeds its book value, goodwill of the reporting unit is not considered impaired. If the book value exceeds fair value, the Company recognizes an impairment loss equal to the difference between book value and fair value.

For further discussion of goodwill impairment losses recognized refer to Note 10, Asset Impairments .

Capitalized Contract Costs

Capitalized contract costs represent the costs directly related and incremental to the origination of new contracts, modification of existing contracts or to the fulfillment of the related customer contracts. These costs include installed products, commissions, other compensation and the cost of installation of new or upgraded customer contracts. The Company calculates amortization by accumulating all deferred contract costs into separate portfolios based on the initial month of service and amortizes those deferred contract costs on a straight-line basis over the expected period of benefit, consistent with the pattern in which the Company provides services to its customers. The expected period of benefit for customers is approximately five years . The Company updates its estimate of the expected period of benefit periodically and whenever events or circumstances indicate that the expected period of benefit could change significantly. Such changes, if any, are accounted for prospectively as a change in estimate. Amortization of capitalized contract costs are included in depreciation and amortization in the consolidated statements of operations. Contract costs not directly related and incremental to the origination of new contracts, modification of existing contracts or to the fulfillment of the related customer contracts are expensed as incurred.

Depreciation and Amortization

The Company's depreciation and amortization included in the consolidated statement of operations consisted of the following:

			For the Year Ended December 31,
(In millions)			2024						2023						2022
Amortization of capitalized contract costs related to fulfillment			$	120					$	37					$	—
Amortization of capitalized contract costs related to customer acquisition			212						131						86
Amortization of customer relationships and other intangible assets			800						870						343
Depreciation of property, plant and equipment			271						257						291
Total depreciation and amortization			$	1,403					$	1,295					$	720

Income Taxes

The Company accounts for income taxes using the liability method in accordance with ASC 740, Income Taxes, or ASC 740, which requires that the Company use the asset and liability method of accounting for deferred income taxes and provide deferred income taxes for all significant temporary differences.

The Company has two categories of income tax expense or benefit — current and deferred, as follows:

• Current income tax expense or benefit consists solely of current taxes payable less applicable tax credits, and

• Deferred income tax expense or benefit is the change in the net deferred income tax asset or liability, excluding amounts charged or credited to accumulated other comprehensive income

The Company reports some of its revenues and expenses differently for financial statement purposes than for income tax return purposes, resulting in temporary and permanent differences between the Company's financial statements and income tax returns. The tax effects of such temporary differences are recorded as either deferred income tax assets or deferred income tax liabilities in the Company's consolidated balance sheets. The Company measures its deferred income tax assets and deferred income tax liabilities using income tax rates that are expected to be in effect when the deferred tax is realized.

The Company accounts for uncertain tax positions in accordance with ASC 740, which applies to all tax positions related to income taxes. Under ASC 740, tax benefits are recognized when it is more-likely-than-not that a tax position will be sustained upon examination by the authorities. The benefit recognized from a position is the amount of benefit that has

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surpassed the more-likely-than-not threshold, as it is more than 50% likely to be realized upon settlement. The Company recognizes interest and penalties accrued related to uncertain tax benefits as a component of income tax expense.

In accordance with ASC 740 and as discussed further in Note 19, Income Taxes , changes to existing net deferred tax assets or valuation allowances or changes to uncertain tax benefits, are recorded to income tax expense/(benefit).

Contract and Emission Credit Amortization

Assets and liabilities recognized through acquisitions related to the purchase and sale of energy and energy-related products in future periods for which the fair value has been determined to be significantly less or more than market are amortized to revenues or cost of operations over the term of each underlying contract based on actual generation and/or contracted volumes.

Emission credits represent the right to emit a specified amount of certain pollutants, including sulfur dioxide, nitrogen oxides and carbon dioxide, over a compliance period. Emission credits held for use are amortized to cost of operations based on the weighted average cost of the allowances held.

Gross Receipts and Sales Taxes

In connection with its retail sales, the Company records gross receipts taxes on a gross basis in revenues and cost of operations in its consolidated statements of operations. During the years ended December 31, 2024, 2023, and 2022, the Company's revenues and cost of operations included gross receipts taxes of $ 216 million, $ 212 million, and $ 218 million, respectively. Additionally, the Company records sales taxes collected from its taxable retail customers and remitted to the various governmental entities on a net basis; thus, there is no impact on the Company's consolidated statement of operations.

Cost of Operations

Cost of operations includes cost of fuel, purchased energy and other costs of sales, mark-to-market for economic hedging activities, contract and emission credit amortization, operations and maintenance, and other cost of operations.

Cost of Fuel, Purchased Energy and Other Cost of Sales

Cost of fuel is primarily the costs associated with procurement, transportation and storage of natural gas, nuclear fuel, oil and coal to operate the generation portfolio, which is expensed as the fuel is consumed. Purchased energy primarily relates to purchases to supply the Company's customer base, which includes spot market purchases, as well as contracts of various quantities and durations, including Renewable PPAs with third-party developers, which are primarily accounted for as NPNS (see further discussion in Derivative Instruments below). Other cost of sales primarily consists of TDSP expenses.

The cost of fuel is based on actual and estimated fuel usage for the applicable reporting period. The cost to deliver energy and related services to customers is based on actual and estimated supply volumes for the applicable reporting period. A portion of the cost of energy, $ 284 million, $ 240 million, and $ 202 million as of December 31, 2024, 2023, and 2022, respectively, was accrued and consisted of estimated transmission and distribution charges not yet billed by the transmission and distribution utilities.

In estimating supply volumes, the Company considers the effects of historical customer volumes, weather factors and usage by customer class. Transmission and distribution delivery fees are estimated using the same method used for electricity sales and services to retail customers. In addition, ISO fees are estimated based on historical trends, estimated supply volumes and initial ISO settlements. Volume estimates are then multiplied by the supply rate and recorded as cost of operations in the applicable reporting period.

Vivint Smart Home Flex Pay

Under the Flex Pay plan (“Flex Pay”), offered by Vivint Smart Home, customers pay separately for smart home products and services (smart home and security). The customer has the ability to pay for Vivint Smart Home products in the following three ways: (i) qualified customers may finance the purchase through third-party financing providers ("Consumer Financing Program" or “CFP”), (ii) Vivint Smart Home generally offers a limited number of customers not eligible for the CFP, but who qualify under Vivint Smart Home underwriting criteria, the option to enter into a retail installment contract directly with Vivint Smart Home or (iii) customers may conduct purchases by check, automatic clearing house payments, credit or debit card or by obtaining short-term financing (generally no more than six-month installment terms) through Vivint Smart Home.

Although customers pay separately for products and services under Flex Pay, the Company has determined that the sale of products and services are one single performance obligation resulting in deferred revenue for the gross amount of products sold. For products financed through the CFP, gross deferred revenues are reduced by (i) any fees the third-party financing provider (“Financing Provider”) is contractually entitled to receive at the time of loan origination, and (ii) the present value of expected future payments due to the Financing Providers . Loans are issued on either an installment or revolving basis with repayment terms ranging from 6 to 60 months.

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For certain Financing Provider loans:

• Vivint Smart Home pays a monthly fee based on either the average daily outstanding balance of the installment loans, or the number of outstanding loans.

• Vivint Smart Home incurs fees at the time of the loan origination and receives proceeds that are net of these fees.

• Vivint Smart Home also shares liability for credit losses.

• Vivint Smart Home is responsible for reimbursing certain Financing Providers for merchant transaction fees and other associated loan fees.

Due to the nature of these provisions, the Company records a derivative liability ("CFP Derivative") at its fair value when the Financing Provider originates loans to customers, which reduces the amount of estimated revenue recognized on the provision of the services. The derivative liability is reduced as payments are made by Vivint Smart Home to the Financing Provider. Subsequent changes to the fair value of the derivative liability are realized through other income, net in the consolidated statements of operations. For further discussion, see Note 6, Accounting for Derivative Instruments and Hedging Activities .

Derivative Instruments

The Company accounts for derivative instruments under ASC 815, which requires the Company to record all derivatives on the balance sheet at fair value and changes in fair value in earnings, unless they qualify for the NPNS exception. The Company's primary derivative instruments are power and natural gas purchase or sales contracts, fuels purchase contracts, the CFP and other energy related commodities used to mitigate variability in earnings due to fluctuation in market prices. In order to mitigate interest rate risk associated with the issuance of the Company's variable rate debt, NRG enters into interest rate swap agreements. In addition, in order to mitigate foreign exchange risk associated with the purchase of USD denominated natural gas for the Company's Canadian business, NRG enters into foreign exchange contract agreements.

As of December 31, 2024 and 2023, the Company did not have derivative instruments that were designated as cash flow or fair value hedges.

Revenues and expenses on contracts that qualify for the NPNS exception are recognized when the underlying physical transaction is delivered. While these contracts are considered derivative instruments under ASC 815, they are not recorded at fair value, but on an accrual basis of accounting. If it is determined that a transaction designated as NPNS no longer meets the scope exception, the fair value of the related contract is recorded on the balance sheet and immediately recognized through earnings.

NRG's trading activities are subject to limits in accordance with the Company's Risk Management Policy. These contracts are recognized on the balance sheet at fair value and changes in the fair value of these derivative instruments are recognized in earnings.

Mark-to-Market for Economic Hedging Activities

NRG enters into derivative instruments to manage price and delivery risk, optimize physical and contractual assets in the portfolio and manage working capital requirements. The mark-to-market for economic hedging activities are recognized to revenues or cost of operations during the reporting period.

Operations and Maintenance and Other Cost of Operations

Operations and maintenance costs include major and other routine preventative (planned outage) and corrective (forced outage) maintenance activities to ensure the safe and reliable operation of the Company's generation portfolio in compliance with all local, state and federal requirements. Operations and maintenance costs are also costs associated with retaining and maintaining the Company's customer base, such as call center support, portfolio maintenance and data analytics. Other cost of operations primarily includes gross receipts taxes, insurance, property taxes and asset retirement obligation expense.

Foreign Currency Translation and Transaction Gains and Losses

The local currencies are generally the functional currency of NRG's foreign operations. Foreign currency denominated assets and liabilities are translated at end-of-period rates of exchange. Revenues, expenses, and cash flows are translated at the weighted-average rates of exchange for the period. The resulting currency translation adjustments are not included in the Company's consolidated statements of operations for the period, but are accumulated and reported as a separate component of stockholders' equity until sale or complete or substantially complete liquidation of the net investment in the foreign entity takes place. Foreign currency transaction gains or losses are reported within other income, net in the Company's consolidated statements of operations. For the years ended December 31, 2024, 2023 and 2022, amounts recognized as foreign currency transaction gains/(losses) were immaterial. The Company's cumulative translation adjustment balances as of December 31, 2024, 2023, and 2022 were $( 72 ) million, $( 43 ) million, and $( 55 ) million, respectively.

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Concentrations of Credit Risk

Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of trust funds, accounts receivable, notes receivable, derivatives and investments in debt securities. Trust funds are held in accounts managed by experienced investment advisors. Certain accounts receivable, notes receivable, and derivative instruments are concentrated within entities engaged in the energy industry. These industry concentrations may impact the Company's overall exposure to credit risk, either positively or negatively, in that the customers may be similarly affected by changes in economic, industry or other conditions. Receivables and other contractual arrangements are subject to collateral requirements under the terms of enabling agreements. However, the Company believes that the credit risk posed by industry concentration is offset by the diversification and creditworthiness of its customer base. See Note 5, Fair Value of Financial Instruments, for a further discussion of derivative concentrations.

Asset Retirement Obligations

The Company accounts for AROs in accordance with ASC 410-20, Asset Retirement Obligations, or ASC 410-20. Retirement obligations associated with long-lived assets included within the scope of ASC 410-20 are those for which a legal obligation exists under enacted laws, statutes, and written or oral contracts, including obligations arising under the doctrine of promissory estoppel, and for which the timing and/or method of settlement may be conditional on a future event. ASC 410-20 requires an entity to recognize the fair value of a liability for an ARO in the period in which it is incurred and a reasonable estimate of fair value can be made.

Upon initial recognition of a liability for an ARO, the Company capitalizes the asset retirement cost by increasing the carrying amount of the related long-lived asset by the same amount. Over time, the liability is accreted to its future value, while the capitalized cost is depreciated over the useful life of the related asset. See Note 13, Asset Retirement Obligations, for a further discussion of AROs.

Pensions and Other Postretirement Benefits

The Company offers pension benefits through a defined benefit pension plan. In addition, the Company provides postretirement health and welfare benefits for certain groups of employees. The Company accounts for pension and other postretirement benefits in accordance with ASC 715, Compensation — Retirement Benefits , or ASC 715 . The Company recognizes the funded status of the Company's defined benefit plans in the statement of financial position and records an offset for gains and losses as well as all prior service costs that have not been included as part of the Company's net periodic benefit cost to other comprehensive income. The determination of the Company's obligation and expenses for pension benefits is dependent on the selection of certain assumptions. These assumptions determined by management include the discount rate, the expected rate of return on plan assets and the rate of future compensation increases. The Company's actuarial consultants assist in determining assumptions for such items as retirement age. The assumptions used may differ materially from actual results, which may result in a significant impact to the amount of pension obligation or expense recorded by the Company.

The Company measures the fair value of its pension assets in accordance with ASC 820, Fair Value Measurements and Disclosures, or ASC 820. For further discussion, see Note 14, Benefit Plans and Other Postretirement Benefits .

Stock-Based Compensation

The Company accounts for its stock-based compensation in accordance with ASC 718, Compensation — Stock Compensation, or ASC 718 . The fair value of the Company's performance stock units is estimated on the date of grant using a Monte Carlo valuation model. NRG uses the Company's common stock price on the date of grant as the fair value of the Company's deferred stock units. Forfeiture rates are estimated based on an analysis of the Company's historical forfeitures, employment turnover, and expected future behavior. The Company recognizes compensation expense for both graded and cliff vesting awards on a straight-line basis over the requisite service period for the entire award. For further discussion, see Note 20, Stock-Based Compensation .

Investments Accounted for by the Equity Method

The Company has investments in domestic energy projects, as well as one Australian project. The equity method of accounting is applied to such investments in affiliates, which include joint ventures and partnerships, because the ownership structure prevents the Company from exercising a controlling influence over the operating and financial policies of the projects. Under this method, equity in pre-tax income or losses of domestic partnerships and, generally, in the net income or losses of its Australian project, are reflected as equity in earnings of unconsolidated affiliates. Distributions from equity method investments that represent earnings on the Company's investment are included within cash flows from operating activities and distributions from equity method investments that represent a return of the Company's investment are included within cash flows from investing activities. For further discussion, see Note 16, Investments Accounted for by the Equity Method and Variable Interest Entities .

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Sale-Leaseback Arrangements

NRG is party to sale-leaseback arrangements that provide for the sale of certain assets to a third-party and simultaneously leases back the same asset to the Company. If the seller-lessee transfers control of the underlying assets to the buyer-lessor, the arrangement is accounted for under ASC 842-40, Sale-Leaseback Transactions . These arrangements are classified as operating leases on the Company's consolidated balance sheets.

Marketing and Advertising Costs

The Company expenses its marketing and advertising costs as incurred and includes them within selling, general and administrative costs. The costs of tangible assets used in advertising campaigns are recorded as fixed assets or deferred advertising costs and amortized as advertising costs over the shorter of the useful life of the asset or the advertising campaign. The Company has several long-term sponsorship arrangements. Payments related to these arrangements are deferred and expensed over the term of the arrangement. Advertising expenses for the years ended December 31, 2024, 2023, and 2022 were $ 215 million, $ 185 million, and $ 82 million, respectively.

Business Combinations

The Company accounts for its business combinations in accordance with ASC 805, Business Combinations, or ASC 805, which requires an acquirer to recognize and measure in its financial statements the identifiable assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at fair value at the acquisition date. The Company also recognizes and measures the goodwill acquired or a gain from a bargain purchase in the business combination. In addition, transaction costs are expensed as incurred.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.

In recording transactions and balances resulting from business operations, the Company uses estimates based on the best information available. Estimates are used for such items as plant depreciable lives, tax provisions, uncollectible accounts, actuarially determined benefit costs, the valuation of energy commodity contracts, environmental liabilities, legal costs incurred in connection with recorded loss contingencies, and assets acquired and liabilities assumed in business combinations, among others. In addition, estimates are used to test long-lived assets and goodwill for impairment and to determine the fair value of impaired assets. As better information becomes available or actual amounts are determinable, the recorded estimates are revised. Consequently, operating results can be affected by revisions to prior accounting estimates.

Reclassifications

Certain prior period amounts have been reclassified for comparative purposes. The reclassifications did not affect results from operations, net assets or cash flows.

Recent Accounting Developments - Guidance Adopted in 2024

ASU 2023-07 – In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280) – Improvements to Reportable Segment Disclosures , or ASU 2023-07. The guidance in ASU 2023-07 enhances reportable segment disclosure requirements by requiring disclosure of significant segment expenses that are regularly provided to the chief operating decision maker and included within each reported measure of segment profit and loss, an amount and description of its composition for other segment items and interim disclosures of a reportable segment’s profit or loss and assets. The Company adopted the amendments effective December 31, 2024. Because the amendments update disclosure requirements only, it did not have an impact on the Company's results of operations, cash flows, or statement of financial position.

Recent Accounting Developments - Guidance Not Yet Adopted

ASU 2023-09 – In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740) – Improvements to Income Tax Disclosures , or ASU 2023-09. The guidance in ASU 2023-09 enhances income tax disclosures by requiring disclosure of specific categories in the effective tax rate reconciliation and additional information for reconciling items that meet a quantitative threshold. Further, the amendments of ASU 2023-09 require certain disclosures on income tax expense and income taxes paid. ASU 2023-09 is effective for annual periods beginning after December 15, 2024, with early adoption permitted. The amendments of ASU 2023-09 may be applied on a prospective or retrospective basis. The Company is currently evaluating the impact of adopting ASU 2023-09 on its disclosures.

ASU 2024-03 – In November 2024, the FASB issued ASU No. 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40) – Disaggregation of Income Statement Expenses , or ASU

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2024-03. The guidance in ASU 2024-03 requires more detailed information about specified categories of expenses included in certain captions presented on the face of the income statement. This ASU is effective for annual periods beginning after December 15, 2026, and interim periods beginning after December 15, 2027. Early adoption is permitted. The amendments may be applied either (1) prospectively to financial statements issued for reporting periods after the effective date of this ASU or (2) retrospectively to all prior periods presented in the financial statements. The Company is currently evaluating the impact of adopting ASU 2024-03 on its disclosures.

ASU 2024-04 – In November 2024, the FASB issued ASU No. 2024-04, Debt—Debt with Conversion and Other Options (Subtopic 470-20) – Induced Conversions of Convertible Debt Instruments , or ASU 2024-04. The guidance in ASU 2024-04 clarifies the requirements related to accounting for the settlement of a debt instrument as an induced conversion when changes are made to conversion features as part of an offer to settle the instrument. This ASU is effective for annual periods beginning after December 15, 2025, with early adoption permitted. The amendments may be applied either (1) prospectively to any settlements of convertible debt instruments that occur after the effective date of this ASU or (2) retrospectively to all prior periods presented in the financial statements, with a cumulative adjustment-effect adjustment to equity. The Company is currently evaluating the impact of adopting ASU 2024-04 on its disclosures.

The Company's policies with respect to its various revenue streams are detailed below. The Company generally applies the invoicing practical expedient to recognize revenue for the revenue streams detailed below, except in circumstances where the invoiced amount does not represent the value transferred to the customer.

Retail Revenue

Gross revenues for energy sales and services to retail customers are recognized as the Company transfers the promised goods and services to the customer. Payment terms are generally 15 to 60 days. For the majority of its electricity and natural gas contracts, the Company’s performance obligation with the customer is satisfied over time and performance obligations for its electricity and natural gas products are recognized as the customer takes possession of the product. The Company also allocates the contract consideration to distinct performance obligations in a contract for which the timing of the revenue recognized is different. Additionally, customer discounts and incentives reduce the contract consideration and are recognized over the term of the contract.

Energy sales and services that have been delivered but not billed by period end are estimated. Accrued unbilled revenues are based on estimates of customer usage since the date of the last meter reading provided by the independent system operators, utilities, or electric distribution companies. Volume estimates are based on daily forecasted volumes and estimated customer usage by class. Unbilled revenues are calculated by multiplying these volume estimates by the applicable rate by customer class. Estimated amounts are adjusted when actual usage is known and billed.

As contracts for retail electricity and natural gas can be for multi-year periods, the Company has performance obligations under these contracts that have not yet been satisfied. These performance obligations have transaction prices that are both fixed and variable, and that vary based on the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the amount of any unsatisfied performance obligations will vary based on customer usage, which will depend on factors such as weather and customer activity and therefore it is not practicable to estimate such amounts.

Vivint Smart Home Retail Revenue

Vivint Smart Home offers its customers combinations of smart home products and services, which together create an integrated smart home system that allows the Company's customers to monitor, control and protect their homes. As the products and services included in the customer's contract are integrated and highly interdependent, and because the products (including installation) and services must work together to deliver the monitoring, controlling and protection of their home, the Company has concluded that the products and services contracted for by the customer are generally not distinct within the context of the contract and, therefore, constitute a single, combined performance obligation. Revenues for this single, combined performance obligation are recognized on a straight-line basis over the customer's contract term, which is the period in which the parties to the contract have enforceable rights and obligations. The Company has determined that certain contracts that do not require a long-term commitment for monitoring services by the customer contain a material right to renew the contract, because the customer does not have to purchase the products upon renewal. Proceeds allocated to the material right are recognized over the expected period of benefit. The majority of Vivint Smart Home's subscription contracts are five years and are generally non-cancelable. These contracts generally convert into month-to-month agreements at the end of the initial term, while some customers are month-to-month from inception. Payment for Vivint Smart Home services is generally due in advance on a monthly basis, with payment terms up to 30 days. Product sales and other one-time fees are invoiced to customers at time of sale. Revenues for any products or services that are considered separate performance obligations are recognized upon delivery. Payments received or billed in advance are reported as deferred revenues.

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Energy Revenue

Both physical and financial transactions consist of revenues billed to a third-party at either market or negotiated contract terms to optimize the financial performance of the Company's generating facilities. Payment terms vary from 5 to 55 days. Electric energy revenue is recognized upon transmission to the customer over time, using the output method for measuring progress of satisfaction of performance obligations. Physical transactions, or the sale of generated electricity to meet supply and demand, are recorded on a gross basis in the Company's consolidated statements of operations. The Company applies the invoicing practical expedient in recognizing energy revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date. Financial transactions used to hedge the sale of electricity are recorded net within revenues in the consolidated statements of operations in accordance with ASC 815.

Ancillary revenues, included in Other revenue, are recognized over time as the obligation is fulfilled, using the output method for measuring progress of satisfaction of performance obligations.

Capacity Revenue

The Company's largest sources of capacity revenues are capacity auctions in PJM and NYISO. Capacity revenues also include revenues billed to a third-party at either market or negotiated contract terms for making installed generation and demand response capacity available in order to satisfy system integrity and reliability requirements. Payment terms vary from 15 to 55 days. Capacity revenues are recognized over time, using the output method for measuring progress of satisfaction of performance obligations. The Company applies the invoicing practical expedient in recognizing capacity revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date.

Performance Obligations

As of December 31, 2024, estimated future fixed fee performance obligations are $ 1.6 billion, $ 1.2 billion, $ 796 million, $ 489 million and $ 219 million for the fiscal years 2025, 2026, 2027, 2028 and 2029, respectively. These performance obligations include Vivint Smart Home products and services, as well as cleared auction MWs in the PJM, ISO-NE, NYISO and MISO capacity auctions. The cleared auction MWs are subject to penalties for non-performance.

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Disaggregated Revenues

The following tables represent the Company’s disaggregation of revenue from contracts with customers for the years ended December 31, 2024, 2023, and 2022:

			For the Year Ended December 31, 2024
(In millions)			Texas						East						West/Services/Other						Vivint Smart Home						Corporate/Eliminations						Total
Retail revenue:
Home			$	6,836					$	2,453					$	1,750					$	1,932					$	( 25 )					$	12,946
Business			3,564						8,794						1,845						—						—						14,203
Total retail revenue (a)			10,400						11,247						3,595						1,932						( 25 )						27,149
Energy revenue (a)			41						242						229						—						( 12 )						500
Capacity revenue (a)			—						156						24						—						( 3 )						177
Mark-to-market for economic hedging activities (b)			—						( 23 )						16						—						4						( 3 )
Contract amortization			—						( 27 )						( 2 )						—						—						( 29 )
Other revenue (a)			212						112						24						—						( 12 )						336
Total revenue			10,653						11,707						3,886						1,932						( 48 )						28,130
Less: Revenues accounted for under topics other than ASC 606 and ASC 815			—						57						61						—						( 1 )						117
Less: Realized and unrealized ASC 815 revenue			30						168						75						—						( 8 )						265
Total revenue from contracts with customers			$	10,623					$	11,482					$	3,750					$	1,932					$	( 39 )					$	27,748
(a) The following table represents the realized revenues related to derivative instruments that are accounted for under ASC 815 and included in the amounts above:
(In millions)			Texas						East						West/Services/Other						Vivint Smart Home						Corporate/Eliminations						Total
Retail revenue			$	—					$	36					$	—					$	—					$	—					$	36
Energy revenue			—						79						63						—						( 12 )						130
Capacity revenue			—						76						—						—						—						76
Other revenue			30						—						( 4 )						—						—						26
(b) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

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			For the Year Ended December 31, 2023
(In millions)			Texas						East						West/Services/Other						Vivint Smart Home (a)						Corporate/Eliminations						Total
Retail revenue:
Home			$	6,538					$	2,195					$	1,890					$	1,549					$	( 1 )					$	12,171
Business			3,492						9,751						2,053						—						—						15,296
Total retail revenue (b)			10,030						11,946						3,943						1,549						( 1 )						27,467
Energy revenue (b)			77						291						185						—						—						553
Capacity revenue (b)			—						197						2						—						( 2 )						197
Mark-to-market for economic hedging activities (c)			—						57						103						—						( 16 )						144
Contract amortization			—						( 32 )						—						—						—						( 32 )
Other revenue (b)			369						88						48						—						( 11 )						494
Total revenue			10,476						12,547						4,281						1,549						( 30 )						28,823
Less: Revenues accounted for under topics other than ASC 606 and ASC 815			—						17						35						—						—						52
Less: Realized and unrealized ASC 815 revenue			29						364						138						—						( 16 )						515
Total revenue from contracts with customers			$	10,447					$	12,166					$	4,108					$	1,549					$	( 14 )					$	28,256
(a) Includes results of operations following the acquisition date of March 10, 2023
(b) The following table represents the realized revenues related to derivative instruments that are accounted for under ASC 815 and included in the amounts above:
(In millions)			Texas						East						West/Services/Other						Vivint Smart Home						Corporate/Eliminations						Total
Retail revenue			$	—					$	74					$	—					$	—					$	—					$	74
Energy revenue			—						162						13						—						1						176
Capacity revenue			—						73						—						—						—						73
Other revenue			29						( 2 )						22						—						( 1 )						48
(c) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

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			For the Year Ended December 31, 2022
(In millions)			Texas						East						West/Services/Other												Corporate/Eliminations						Total
Retail revenue:
Home			$	6,388					$	2,088					$	2,286											$	( 1 )					$	10,761
Business			3,229						13,768						1,964												—						18,961
Total retail revenue (a)			9,617						15,856						4,250												( 1 )						29,722
Energy revenue (a)			111						641						466												32						1,250
Capacity revenue (a)			—						232						40												—						272
Mark-to-market for economic hedging activities (b)			2						( 30 )						( 56 )												1						( 83 )
Contract amortization			—						( 40 )						1												—						( 39 )
Other revenue (a)			327						104						5												( 15 )						421
Total revenue			10,057						16,763						4,706												17						31,543
Less: Revenues accounted for under topics other than ASC 606 and ASC 815			—						( 7 )						41												1						35
Less: Realized and unrealized ASC 815 revenue			( 2 )						84						( 93 )												31						20
Total revenue from contracts with customers			$	10,059					$	16,686					$	4,758											$	( 15 )					$	31,488
(a) The following table represents the realized revenues related to derivative instruments that are accounted for under ASC 815 and included in the amounts above:
(In millions)			Texas						East						West/Services/Other												Corporate/Eliminations						Total
Retail revenue			$	—					$	110					$	—											$	—					$	110
Energy revenue			—						( 31 )						( 8 )												31						( 8 )
Capacity revenue			—						33						—												—						33
Other revenue			( 4 )						2						( 29 )												( 1 )						( 32 )
(b) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

Contract Balances

The following table reflects the contract assets and liabilities included in the Company's balance sheet as of December 31, 2024 and 2023:

(In millions)						December 31, 2024						December 31, 2023
Capitalized contract costs (included in Prepayments and other current assets and Other non-current assets)						$	1,220					$	706
Accounts receivable, net - Contracts with customers						3,393						3,395
Accounts receivable, net - Accounted for under topics other than ASC 606						90						136
Accounts receivable, net - Affiliate						5						11
Total accounts receivable, net						$	3,488					$	3,542
Unbilled revenues (included within Accounts receivable, net - Contracts with customers)						$	1,548					$	1,493
Deferred revenues (a)						$	1,573					$	1,634

(a) Deferred revenues from contracts with customers as of December 31, 2024 and 2023 were approximately $ 1.5 billion and $ 1.6 billion, respectively.

The revenue recognized from contracts with customers during the years ended December 31, 2024 and 2023 relating to the deferred revenue balance at the beginning of each period was $ 606 million and $ 168 million, respectively, which increased primarily due to the acquisition of Vivint Smart Home.

The Company's capitalized contract costs consist of fulfillment costs, commission payments, broker fees and other costs that represent incremental costs of obtaining the contract with customers for which the Company expects to recover. Capitalized contract costs are amortized to depreciation and amortization on a straight-line basis over the expected period of benefit of five years .

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When the Company receives consideration from the customer that is in excess of the amount due, such consideration is reclassified to deferred revenue, which represents a contract liability. Smart home products and services performance obligations are recognized over the customer's contract term, which is generally three to five years . Energy contract liabilities are generally recognized to revenue in the next period as the Company satisfies its performance obligations.

Acquisitions

2023 Acquisition

Vivint Smart Home Acquisition

On March 10, 2023 (the "Acquisition Closing Date"), the Company completed the acquisition of Vivint Smart Home, Inc., pursuant to the Agreement and Plan of Merger, dated as of December 6, 2022, by and among the Company, Vivint Smart Home, Inc. and Jetson Merger Sub, Inc., a wholly-owned subsidiary of the Company (“Merger Sub”) pursuant to which Merger Sub merged with and into Vivint Smart Home, Inc., with Vivint Smart Home, Inc. surviving the merger as a wholly-owned subsidiary of the Company. Dedicated to redefining the home experience with intelligent products and services, Vivint Smart Home brought approximately two million subscribers to NRG. Vivint Smart Home's single, expandable platform incorporates artificial intelligence and machine learning into its operating system and its vertically integrated business model includes hardware, software, sales, installation, customer service and technical support and professional monitoring, enabling superior subscriber experiences and a complete end-to-end smart home experience. The acquisition accelerated the realization of NRG's consumer-focused growth strategy and creates a leading essential home services platform fueled by market-leading brands, unparalleled insights, proprietary technologies and complementary sales channels.

NRG paid $ 12 per share, or approximately $ 2.6 billion in cash. The Company funded the acquisition using:

• proceeds of $ 724 million from newly issued $ 740 million 7.000 % Senior Secured First Lien Notes due 2033, net of issuance costs and discount;

• proceeds of $ 635 million from newly issued $ 650 million 10.25 % Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock, net of issuance costs;

• proceeds of approximately $ 900 million drawn from its Revolving Credit Facility and Receivables Securitization Facilities; and

• cash on hand.

Acquisition costs of $ 38 million and $ 17 million for the years ended December 31, 2023 and 2022, respectively, are included in acquisition-related transaction and integration costs in the Company's consolidated statement of operations.

The acquisition has been recorded as a business combination under ASC 805, with identifiable assets and liabilities acquired recorded at their estimated Acquisition Closing Date fair value. The total consideration of $ 2.623 billion includes:

						(In millions)
Vivint Smart Home, Inc. common shares outstanding as of March 10, 2023 of 216,901,639 at $ 12.00 per share						$	2,603
Other Vivint Smart Home, Inc. equity instruments (Cash out RSUs and PSUs, Stock Appreciation Rights, Private Placement Warrants)						6
Total Cash Consideration						$	2,609
Fair value of acquired Vivint Smart Home, Inc. equity awards attributable to pre-combination service						14
Total Consideration						$	2,623

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The purchase price was allocated as follows as of December 31, 2023:

			(In millions)
Current Assets
Cash and cash equivalents			$	120
Accounts receivable, net			60
Inventory			113
Prepayments and other current assets			37
Total current assets			330
Property, plant and equipment, net			49
Other Assets
Operating lease right-of-use assets, net			35
Goodwill (a)			3,494
Intangible assets, net (b) :
Customer relationships			1,740
Technology			860
Trade names			160
Sales channel contract			10
Intangible assets, net			2,770
Deferred income taxes			382
Other non-current assets			14
Total other assets			6,695
Total Assets			$	7,074
Current Liabilities
Current portion of long-term debt and finance leases			$	14
Current portion of operating lease liabilities			13
Accounts payable			109
Derivative instruments			80
Deferred revenue current			518
Accrued expenses and other current liabilities			207
Total current liabilities			941
Other Liabilities
Long-term debt and finance leases			2,572
Non-current operating lease liabilities			28
Derivative instruments			32
Deferred income taxes			18
Deferred revenue non-current			837
Other non-current liabilities			23
Total other liabilities			3,510
Total Liabilities			$	4,451
Vivint Smart Home Purchase Price			$	2,623

(a) Goodwill arising from the acquisition is attributed to the value of the platform acquired, cross-selling opportunities, subscriber growth and the synergies expected from combining the operations of Vivint Smart Home with NRG's existing businesses. None of the goodwill recorded will be deductible for tax purposes

(b) The weighted average amortization period for total amortizable intangible assets is approximately ten years

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Dispositions

2024 Disposition

Sale of Airtron

On September 16, 2024, the Company closed on the sale of its 100 % ownership in the Airtron business unit. Proceeds of $ 500 million were reduced by working capital and other adjustments of $ 20 million, resulting in net proceeds of $ 480 million. The Company recorded a gain on the sale of $ 204 million within the West/Services/Other region of operations.

2023 Dispositions

Sale of the 44 % equity interest in STP

On November 1, 2023, the Company closed on the sale of its 44 % equity interest in STP to Constellation Energy Generation ("Constellation"). Proceeds of $ 1.75 billion were reduced by working capital and other adjustments of $ 96 million, resulting in net proceeds of $ 1.654 billion. The Company recorded a gain on the sale of $ 1.2 billion within the Texas region of operations. For discussion of the litigation matter related to the transaction, see Note 22, Commitments and Contingencies.

Sale of Gregory

On October 2, 2023, the Company closed on the sale of its 100 % ownership in the Gregory natural gas generating facility in Texas for $ 102 million. The Company recorded a gain on the sale of $ 82 million .

Sale of Astoria

On January 6, 2023, the Company closed on the sale of land and related generation assets from the Astoria site, within the East region of operations, for proceeds of $ 212 million, subject to transaction fees of $ 3 million and certain indemnifications, resulting in a $ 199 million gain.

2022 Disposition

Sale of Watson

On June 1, 2022, the Company closed on the sale of its 49 % ownership in the Watson natural gas generating facility for $ 59 million. The Company recorded a gain on the sale of $ 46 million within the West/Services/Other region of operations.

For cash and cash equivalents, funds deposited by counterparties, restricted cash, accounts and other receivables, accounts payable and cash collateral paid and received in support of energy risk management activities, the carrying amount approximates fair value because of the short-term maturity of those instruments and are classified as Level 1 within the fair value hierarchy.

The estimated carrying value and fair value of the Company's long-term debt, including current portion, is as follows:

			As of December 31,
			2024												2023
(In millions)			Carrying Amount						Fair Value						Carrying Amount						Fair Value
Convertible Senior Notes			$	232					$	509					$	575					$	739
Other long-term debt, including current portion			10,648						10,252						10,219						9,835
Total long-term debt, including current portion (a)			$	10,880					$	10,761					$	10,794					$	10,574

(a) Excludes deferred financing costs, which are recorded as a reduction to long-term debt on the Company's consolidated balance sheets

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The fair value of the Company's publicly-traded long-term debt, the Term Loans and the Vivint Senior Secured Term Loan are based on quoted market prices and are classified as Level 2 within the fair value hierarchy.

Fair Value Accounting under ASC 820

ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:

• Level 1 — quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the measurement date. NRG's financial assets and liabilities utilizing Level 1 inputs include active exchange-traded securities, energy derivatives, and trust fund investments.

• Level 2 — inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data. NRG's financial assets and liabilities utilizing Level 2 inputs include fixed income securities, exchange-based derivatives, and over the counter derivatives such as swaps, options and forward contracts.

• Level 3 — unobservable inputs for the asset or liability only used when there is little, if any, market activity for the asset or liability at the measurement date. NRG's financial assets and liabilities utilizing Level 3 inputs include infrequently-traded, non-exchange-based derivatives and commingled investment funds, and are measured using present value pricing models.

In accordance with ASC 820, the Company determines the level in the fair value hierarchy within which each fair value measurement in its entirety falls, based on the lowest level input that is significant to the fair value measurement in its entirety.

Recurring Fair Value Measurements

Derivative assets and liabilities, debt securities, equity securities and trust fund investments, which were comprised of various U.S. debt and equity securities, are carried at fair market value.

The following tables present assets and liabilities measured and recorded at fair value on the Company's consolidated balance sheets on a recurring basis and their level within the fair value hierarchy:

			As of December 31, 2024
			Fair Value
(In millions)			Total						Level 1						Level 2						Level 3
Investments in securities (classified within other current and non-current assets)			$	28					$	—					$	28					$	—
Derivative assets:
Interest rate contracts			9						—						9						—
Foreign exchange contracts			22						—						22						—
Commodity contracts (a)			3,368						528						2,645						195
Equity securities measured using net asset value practical expedient (classified within other non-current assets)			6
Total assets			$	3,433					$	528					$	2,704					$	195
Derivative liabilities:
Interest rate contracts			$	3					$	—					$	3					$	—
Foreign exchange contracts			1						—						1						—
Commodity contracts (a)			2,970						432						2,382						156
Consumer Financing Program			203						—						—						203
Total liabilities			$	3,177					$	432					$	2,386					$	359

(a) Excludes $ 997 million of derivative assets and $ 227 million of derivative liabilities that were elected as NPNS on October 1, 2024 and are no longer valued at fair value on a recurring basis. For further discussion, see Item 15 — Note 6, Accounting for Derivative Instruments and Hedging Activities

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			As of December 31, 2023
			Fair Value
(In millions)			Total						Level 1						Level 2						Level 3
Investments in securities (classified within other current and non-current assets)			$	21					$	—					$	21					$	—
Derivative assets:
Interest rate contracts			12						—						12						—
Foreign exchange contracts			5						—						5						—
Commodity contracts			6,138						1,334						4,470						334
Equity securities measured using net asset value practical expedient (classified within other non-current assets)			6
Total assets			$	6,182					$	1,334					$	4,508					$	334
Derivative liabilities:
Interest rate contracts			$	8					$	—					$	8					$	—
Foreign exchange contracts			9						—						9						—
Commodity contracts			5,356						1,413						3,728						215
Consumer Financing Program			134						—						—						134
Total liabilities			$	5,507					$	1,413					$	3,745					$	349

The following table reconciles, for the years ended December 31, 2024 and 2023, the beginning and ending balances for financial instruments that are recognized at fair value in the consolidated financial statements using significant unobservable inputs, for commodity derivatives:

						Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
						Commodity Derivatives (a)
						For the Year Ended December 31,
(In millions)						2024						2023
Beginning balance						$	119					$	505
Total (losses) realized/unrealized included in earnings						( 113 )						( 164 )
Purchases						42						42
Transfers into Level 3 (b)						2						78
Transfers out of Level 3 (b)(c)						( 11 )						( 342 )
Ending balance						$	39					$	119
(Losses) for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of year-end						$	( 55 )					$	( 46 )

(a) Consists of derivatives assets and liabilities, net, excluding derivative liabilities from Consumer Financing Program, which are presented in a separate table below

(b) Transfers into/out of Level 3 are related to the availability of consensus pricing and external broker quotes, and are valued as of the end of the reporting period. Except for the transfers out of Level 3 noted below, all other transfers into/out of Level 3 are from/to Level 2

(c) For the year ended December 31, 2023, due to the change to use consensus pricing, there was a decrease in the number of contracts valued with prices provided by models and other valuation techniques, which resulted in a large transfer out of Level 3

Realized and unrealized gains and losses included in earnings that are related to the commodity derivatives are recorded in revenues and cost of operations.

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The following table reconciles, for the years ended December 31, 2024 and 2023, the beginning and ending balances of the contractual obligations from the Consumer Financing Program that are recognized at fair value in the condensed consolidated financial statements, using significant unobservable inputs:

			Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
			Consumer Financing Program
			For the Year Ended December 31,
(In millions)			2024						2023
Beginning balance			$	( 134 )					$	—
Contractual obligations added from the acquisition of Vivint Smart Home			—						( 112 )
New contractual obligations			( 147 )						( 68 )
Settlements			92						62
Total losses included in earnings			( 14 )						( 16 )
Ending balance			$	( 203 )					$	( 134 )

Gains and losses that are related to the Consumer Financing Program derivative are recorded in other income, net.

Derivative fair value measurements

The Company's contracts consist of non-exchange-traded contracts valued using prices provided by external sources and exchange-traded contracts with readily available quoted market prices. Beginning in of the fourth quarter of 2023, the fair value of non-exchange traded contracts were based on consensus pricing provided by independent pricing services. The pricing data was compiled from market makers with longer dated tenors as compared to broker quotes, enhancing reliability and increasing transparency.

Prior to the fourth quarter of 2023, the Company valued derivatives based on price quotes from brokers in active markets who regularly facilitate those transactions. For the majority of markets that NRG participates in, the Company would receive broker quotes from multiple sources and reflected the average of the bid-ask mid-point prices. The terms for which such price information is available vary by commodity, region and product. The Company believes both sources of price quotes are executable.

The remainder of the assets and liabilities represents contracts for which external sources or observable market quotes are not available. These contracts are valued based on various valuation techniques including but not limited to internal models based on a fundamental analysis of the market and extrapolation of observable market data with similar characteristics. As of December 31, 2024, contracts valued with prices provided by models and other valuation techniques make up 6 % of derivative assets and 11 % of derivative liabilities. The fair value of each contract is discounted using a risk free interest rate. In addition, the Company applies a credit reserve to reflect credit risk, which for foreign exchange contracts and interest rate swaps is calculated utilizing the bilateral method based on published default probabilities. For commodities, to the extent that NRG's net exposure under a specific master agreement is an asset, the Company uses the counterparty's default swap rate. If the exposure under a specific master agreement is a liability, the Company uses NRG's default swap rate. For foreign exchange contracts, interest rate swaps, and commodities, the credit reserve is added to the discounted fair value to reflect the exit price that a market participant would be willing to receive to assume NRG's liabilities or that a market participant would be willing to pay for NRG's assets. As of December 31, 2024, the credit reserve resulted in a $ 1 million decrease primarily within cost of operations. As of December 31, 2023, the credit reserve resulted in $ 18 million decrease primarily within cost of operations.

The fair values in each category reflect the level of forward prices and volatility factors as of December 31, 2024 and may change as a result of changes in these factors. Management uses its best estimates to determine the fair value of commodity and derivative contracts NRG holds and sells. These estimates consider various factors including closing exchange, consensus and over-the-counter price quotations, time value, volatility factors and credit exposure. It is possible, however, that future market prices could vary from those used in recording assets and liabilities from energy marketing and trading activities and such variations could be material.

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NRG's significant positions classified as Level 3 include physical and financial natural gas, power, capacity contracts and renewable energy certificates executed in illiquid markets as well as financial transmission rights ("FTRs"). The significant unobservable inputs used in developing fair value include illiquid natural gas and power location pricing, which is derived as a basis to liquid locations. The basis spread is based on observable market data when available or derived from historic prices and forward market prices from similar observable markets when not available. Forward capacity prices are based on market information, forecasted future electricity demand and supply, past auctions and internally developed pricing models. Renewable energy certificate prices are based on market information and internally developed pricing models. For FTRs, NRG uses the most recent auction prices to derive the fair value. The Consumer Financing Program derivatives are valued using a discounted cash flow model, with inputs consisting of available market data, such as market yield discount rates, as well as unobservable internally derived assumptions, such as collateral prepayment rates, collateral default rates and credit loss rates.

The following tables quantify the significant unobservable inputs used in developing the fair value of the Company's Level 3 positions as of December 31, 2024 and 2023:

			Significant Unobservable Inputs
			December 31, 2024
			Fair Value																								Input/Range
(in millions, except as noted)			Assets						Liabilities						Valuation Technique						Significant Unobservable Input						Low						High						Weighted Average
Natural Gas Contracts			$	56					$	15					Discounted Cash Flow						Forward Market Price ($ per MMBtu)						$	2					$	27					$	4
Power Contracts			57						86						Discounted Cash Flow						Forward Market Price ($ per MWh)						0						109						39
Capacity Contracts			34						13						Discounted Cash Flow						Forward Market Price ($ per MW/Day)						16						510						220
Renewable Energy Certificates			30						14						Discounted Cash Flow						Forward Market Price ($ per Certificate)						2						375						15
FTRs			18						28						Discounted Cash Flow						Auction Prices ($ per MWh)						( 50 )						16,180						0
Consumer Financing Program			—						203						Discounted Cash Flow						Collateral Default Rates						0.52		%				76.80		%				11.71		%
															Discounted Cash Flow						Collateral Prepayment Rates						2.00		%				3.00		%				2.83		%
															Discounted Cash Flow						Credit Loss Rates						6.00		%				60.00		%				14.22		%
			$	195					$	359

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			Significant Unobservable Inputs
			December 31, 2023
			Fair Value																								Input/Range
(in millions, except as noted)			Assets						Liabilities						Valuation Technique						Significant Unobservable Input						Low						High						Weighted Average
Natural Gas Contracts			$	39					$	65					Discounted Cash Flow						Forward Market Price ($ per MMBtu)						$	1					$	15					$	3
Power Contracts			197						66						Discounted Cash Flow						Forward Market Price ($ per MWh)						1						210						47
Capacity Contracts			21						33						Discounted Cash Flow						Forward Market Price ($ per MW/Day)						49						658						285
Renewable Energy Certificates			58						14						Discounted Cash Flow						Forward Market Price ($ per Certificate)						2						320						15
FTRs			19						37						Discounted Cash Flow						Auction Prices ($ per MWh)						( 58 )						252						0
Consumer Financing Program			—						134						Discounted Cash Flow						Collateral Default Rates						0.43		%				93.30		%				8.12		%
															Discounted Cash Flow						Collateral Prepayment Rates						2.00		%				3.00		%				2.95		%
															Discounted Cash Flow						Credit Loss Rates						6.00		%				60.00		%				12.57		%
			$	334					$	349

The following table provides sensitivity of fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2024 and 2023:

Significant Unobservable Input

Position

Change In Input

Impact on Fair Value Measurement

Forward Market Price Natural Gas/Power/Capacity/Renewable Energy Certificates

Buy

Increase/(Decrease)

Higher/(Lower)

Forward Market Price Natural Gas/Power/Capacity/Renewable Energy Certificates

Sell

Increase/(Decrease)

Lower/(Higher)

FTR Prices

Buy

Increase/(Decrease)

Higher/(Lower)

FTR Prices

Sell

Increase/(Decrease)

Lower/(Higher)

Collateral Default Rates

n/a

Increase/(Decrease)

Higher/(Lower)

Collateral Prepayment Rates

n/a

Increase/(Decrease)

Lower/(Higher)

Credit Loss Rates

n/a

Increase/(Decrease)

Higher/(Lower)

Under the guidance of ASC 815, entities may choose to offset cash collateral posted or received against the fair value of derivative positions executed with the same counterparties under the same master netting agreements. The Company has chosen not to offset positions as defined in ASC 815. As of December 31, 2024, the Company recorded $ 309 million of cash collateral posted and $ 199 million of cash collateral received on its balance sheet.

Concentration of Credit Risk

In addition to the credit risk discussion as disclosed in Note 2, Summary of Significant Accounting Policies , the following item is a discussion of the concentration of credit risk for the Company's financial instruments. Credit risk relates to the risk of loss resulting from non-performance or non-payment by counterparties pursuant to the terms of their contractual obligations. The Company monitors and manages credit risk through credit policies that include: (i) an established credit approval process; (ii) a daily monitoring of counterparties' credit limits; (iii) the use of credit mitigation measures such as margin, collateral, prepayment arrangements, or volumetric limits; (iv) the use of payment netting agreements; and (v) the use of master netting

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agreements that allow for the netting of positive and negative exposures of various contracts associated with a single counterparty. Risks surrounding counterparty performance and credit could ultimately impact the amount and timing of expected cash flows. The Company seeks to mitigate counterparty risk by having a diversified portfolio of counterparties. The Company also has credit protection within various agreements to call on additional collateral support if and when necessary. Cash margin is collected and held at the Company to cover the credit risk of the counterparty until positions settle.

Counterparty Credit Risk

As of December 31, 2024, counterparty credit exposure, excluding credit exposure from RTOs, ISOs, and registered commodity exchanges and certain long-term agreements, was $ 1.7 billion and NRG held collateral (cash and letters of credit) against those positions of $ 288 million, resulting in a net exposure of $ 1.5 billion. NRG periodically receives collateral from counterparties in excess of their exposure. Collateral amounts shown include such excess while net exposure shown excludes excess collateral received. Approximately 69 % of the Company's exposure before collateral is expected to roll off by the end of 2026. Counterparty credit exposure is valued through observable market quotes and discounted at a risk free interest rate. The following tables highlight net counterparty credit exposure by industry sector and by counterparty credit quality. Net counterparty credit exposure is defined as the aggregate net asset position for NRG with counterparties where netting is permitted under the enabling agreement and includes all cash flow, mark-to-market and NPNS, and non-derivative transactions. The exposure is shown net of collateral held and includes amounts net of receivables or payables.

Category			Net Exposure (a) (b) (% of Total)
Utilities, energy merchants, marketers and other			74		%
Financial institutions			26
Total			100		%

Category			Net Exposure (a) (b) (% of Total)
Investment grade			55		%
Non-Investment grade/Non-Rated			45
Total			100		%

(a) Counterparty credit exposure excludes coal transportation contracts because of the unavailability of market prices

(b) The figures in the tables above exclude potential counterparty credit exposure related to RTOs, ISOs, registered commodity exchanges and certain long term contracts

The Company had no exposure to wholesale counterparties in excess of 10 % of the total net exposure discussed above as of December 31, 2024. Changes in hedge positions and market prices will affect credit exposure and counterparty concentration.

RTOs and ISOs

The Company participates in the organized markets of CAISO, ERCOT, AESO, IESO, ISO-NE, MISO, NYISO and PJM, known as RTOs or ISOs. Trading in the majority of these markets is approved by FERC, whereas in the case of ERCOT, it is approved by the PUCT, and whereas in the case of AESO and IESO, both exist provincially with AESO primarily subject to Alberta Utilities Commission and the IESO subject to the Ontario Energy Board. These ISOs may include credit policies that, under certain circumstances, require that losses arising from the default of one member on spot market transactions be shared by the remaining participants. As a result, the counterparty credit risk to these markets is limited to NRG’s share of the overall market and are excluded from the above exposures.

Exchange Traded Transactions

The Company enters into commodity transactions on registered exchanges, notably ICE, NYMEX and Nodal. These clearinghouses act as the counterparty and transactions are subject to extensive collateral and margining requirements. As a result, these commodity transactions have limited counterparty credit risk.

Long-Term Contracts

Counterparty credit exposure described above excludes credit risk exposure under certain long term contracts, primarily solar under Renewable PPAs. As external sources or observable market quotes are not always available to estimate such exposure, the Company values these contracts based on various techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of observable market data with similar characteristics. Based on these valuation techniques, as of December 31, 2024, aggregate credit risk exposure managed by NRG to these counterparties was approximately $ 868 million for the next five years.

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Retail Customer Credit Risk

The Company is exposed to retail credit risk through the Company's retail electricity and gas providers, which serve Home and Business customers. Retail credit risk results in losses when a customer fails to pay for services rendered. The losses may result from both nonpayment of customer accounts receivable and the loss of in-the-money forward value. The Company manages retail credit risk through the use of established credit policies that include monitoring of the portfolio and the use of credit mitigation measures such as deposits or prepayment arrangements.

As of December 31, 2024, the Company's retail customer credit exposure to Home and Business customers was diversified across many customers and various industries, as well as government entities. Current economic conditions may affect the Company's customers' ability to pay bills in a timely manner, which could increase customer delinquencies and may lead to an increase in credit losses. The Company's provision for credit losses was $ 314 million, $ 251 million, and $ 11 million for the years ended December 31, 2024, 2023, and 2022, respectively. During the year ended December 31, 2022, the provision for credit losses included the Company's loss mitigation efforts recognized as income of $ 126 million related to Winter Storm Uri.

ASC 815 requires the Company to recognize all derivative instruments on the balance sheet as either assets or liabilities and to measure them at fair value each reporting period unless they qualify for a NPNS exception. The Company may elect to designate certain derivatives as cash flow hedges, if certain conditions are met, and defer the change in fair value of the derivatives to accumulated OCI, until the hedged transactions occur and are recognized in earnings.

For derivatives that are not designated as cash flow hedges or do not qualify for hedge accounting treatment, the changes in the fair value will be immediately recognized in earnings. Certain derivative instruments may qualify for the NPNS exception and are therefore exempt from fair value accounting treatment. ASC 815 applies to NRG's energy related commodity contracts, foreign exchange contracts, interest rate swaps and Consumer Financing Program.

As the Company engages principally in the trading and marketing of its generation assets and retail operations, some of NRG's commercial activities qualify for NPNS accounting. Most of the retail load contracts either qualify for the NPNS exception or fail to meet the criteria for a derivative and the majority of the retail supply and fuels supply contracts are recorded under mark-to-market accounting. All of NRG's hedging and trading activities are subject to limits within the Company's Risk Management Policy.

On October 1, 2024, the Company elected NPNS for certain existing derivative contracts. Upon election of NPNS, the Company discontinued derivative accounting treatment and will no longer remeasure the derivative contracts at fair value each reporting period. The fair values of these derivative contracts were frozen as of October 1, 2024 and the Company is derecognizing the fair values to earnings at the same time as the contracts mature. The values of these contracts are included in Derivative instruments captions in the Consolidated Balance Sheets. Subsequent to the election date, costs associated with these contracts will be recorded when the underlying physical transaction is delivered. These derivative contracts extend through 2036.

Energy-Related Commodities

To manage the commodity price risk associated with the Company's competitive supply activities and the price risk associated with wholesale power sales from the Company's electric generation facilities and retail power and gas sales from NRG's retail operations, NRG enters into a variety of derivative and non-derivative hedging instruments, utilizing the following:

• Forward contracts, which commit NRG to purchase or sell energy commodities or fuels in the future;

• Futures contracts, which are exchange-traded standardized commitments to purchase or sell a commodity or financial instrument;

• Swap agreements, which require payments to or from counterparties based upon the differential between two prices for a predetermined contractual, or notional, quantity;

• Option contracts, which convey to the option holder the right but not the obligation to purchase or sell a commodity; and

• Weather derivative products used to mitigate a portion of lost revenue due to weather.

The objectives for entering into derivative contracts designated as hedges include:

• Fixing the price of a portion of anticipated power and gas purchases for the Company's retail sales;

• Fixing the price for a portion of anticipated future electricity sales that provides an acceptable return on the Company's electric generation operations; and

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• Fixing the price of a portion of anticipated fuel purchases for the operation of the Company's power plants.

These contracts are recognized on the balance sheet at fair value and changes in the fair value of these derivative financial instruments are recognized in earnings.

As of December 31, 2024, NRG's derivative assets and liabilities consisted primarily of the following:

• Forward and financial contracts for the purchase/sale of electricity and related products economically hedging NRG's generation assets' forecasted output or NRG's retail load obligations through 2034;

• Forward and financial contracts for the purchase of fuel commodities relating to the forecasted usage of NRG's generation assets through 2026;

• Other energy derivatives instruments extending through 2029.

Also, as of December 31, 2024, NRG had other energy-related contracts that did not meet the definition of a derivative instrument or qualified for the NPNS exception and were therefore exempt from fair value accounting treatment as follows:

• Load-following forward electric sale contracts extending through 2037;

• Load-following forward natural gas purchase and sale contracts extending through 2032;

• Power tolling contracts through 2036;

• Coal purchase contracts through 2027;

• Power transmission contracts through 2030;

• Natural gas transportation contracts through 2034;

• Natural gas storage agreements through 2030; and

• Coal transportation contracts through 2029.

Foreign Exchange Contracts

In order to mitigate foreign exchange risk primarily associated with the purchase of USD denominated natural gas for the Company's Canadian business, NRG enters into foreign exchange contract agreements through 2028.

Interest Rate Swaps

NRG is exposed to changes in interest rate through the Company's issuance of variable rate debt. To manage the Company's interest rate risk, NRG enters into interest rate swap agreements. The Company had $ 1.0 billion of interest rate swaps extending through 2027 to hedge the floating rate of the Vivint Term Loans and interest rate swaps with a total nominal value of $ 700 million extending through 2029 to hedge the floating rate of the Term Loans which were terminated in November 2024. In November 2024, in connection with the amendment of the Term Loans, the Company entered into $ 700 million of interest rate swaps through 2029 to hedge its floating rate.

Consumer Financing Program

Under the Consumer Financing Program, Vivint Smart Home pays a monthly fee to Financing Providers based on either the average daily outstanding balance of the loans or the number of outstanding loans. For certain loans, Vivint Smart Home incurs fees at the time of the loan origination and receives proceeds that are net of these fees. Vivint Smart Home also shares the liability for credit losses, depending on the credit quality of the customer. Due to the nature of certain provisions under the Consumer Financing Program, the Company records a derivative liability that is not designated as a hedging instrument and is adjusted to fair value, measured using the present value of the estimated future payments. Changes to the fair value are recorded through other income, net in the consolidated statement of operations. The following represent the contractual future payment obligations with the Financing Providers under the Consumer Financing Program that are components of the derivative:

•    Vivint Smart Home pays either a monthly fee based on the average daily outstanding balance of the loans, or the number of outstanding loans, depending on the Financing Provider;

•    Vivint Smart Home shares the liability for credit losses depending on the credit quality of the customer; and

•    Vivint Smart Home pays transactional fees associated with customer payment processing.

The derivative is classified as a Level 3 instrument. The derivative positions are valued using a discounted cash flow model, with inputs consisting of available market data, such as market yield discount rates, as well as unobservable internally derived assumptions, such as collateral prepayment rates, collateral default rates and credit loss rates. In summary, the fair value represents an estimate of the present value of the cash flows Vivint Smart Home will be obligated to pay to the Financing Provider for each component of the derivative.

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Volumetric Underlying Derivative Transactions

The following table summarizes the net notional volume buy/(sell) of NRG's open derivative transactions broken out by commodity, excluding those derivatives that qualified for the NPNS exception as of December 31, 2024 and 2023. Option contracts are reflected using delta volume. Delta volume equals the notional volume of an option adjusted for the probability that the option will be in-the-money at its expiration date.

						Total Volume (In millions)
Category			Units			December 31, 2024						December 31, 2023
Emissions			Short Ton			1						—
Renewables Energy Certificates			Certificates			13						12
Coal			Short Ton			10						9
Natural Gas			MMBtu			861						838
Power			MWh			91						201
Interest			Dollars			700						1,000
Foreign Exchange			Dollars			410						548
Consumer Financing Program			Dollars			1,219						1,116

Fair Value of Derivative Instruments

The following table summarizes the fair value within the derivative instrument valuation on the balance sheet:

			Fair Value
			Derivative Assets												Derivative Liabilities
(In millions)			December 31, 2024						December 31, 2023						December 31, 2024						December 31, 2023
Derivatives Not Designated as Cash Flow or Fair Value Hedges :
Interest rate contracts - current			$	—					$	12					$	3					$	—
Interest rate contracts - long-term			9						—						—						8
Foreign exchange contracts - current			15						3						—						4
Foreign exchange contracts - long-term			7						2						1						5
Commodity contracts- current			2,295						3,847						2,067						3,922
Commodity contracts- long-term			1,073						2,291						903						1,434
Consumer Financing Program - current			—						—						137						93
Consumer Financing Program - long-term			—						—						66						41
Derivatives Not Designated as Cash Flow or Fair Value Hedges			$	3,399					$	6,155					$	3,177					$	5,507
Deferred gains/losses on NPNS contracts - current			376						—						90						—
Deferred gains/losses on NPNS contracts - long-term			621						—						137						—
Deferred gains/losses on NPNS contracts (a)			$	997					$	—					$	227					$	—
Total Derivatives Not Designated as Cash Flow or Fair Value Hedges			$	4,396					$	6,155					$	3,404					$	5,507

(a) Balances related to certain derivative contracts that were previously accounted for as derivative contracts following the election of the NPNS exemption and the discontinuance of derivative accounting treatment as of the election date

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The Company has elected to present derivative assets and liabilities on the balance sheet on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. In addition, collateral received or paid on the Company's derivative assets or liabilities are recorded on a separate line item on the balance sheet. The following table summarizes the offsetting derivatives by counterparty master agreement level and collateral received or paid:

			Gross Amounts Not Offset in the Statement of Financial Position
(In millions)			Gross Amounts of Recognized Assets/Liabilities						Derivative Instruments						Cash Collateral (Held)/Posted						Net Amount
As of December 31, 2024
Interest rate contracts:
Derivative assets			$	9					$	( 3 )					$	—					$	6
Derivative liabilities			( 3 )						3						—						—
Total interest rate contracts			6						—						—						6
Foreign exchange contracts:
Derivative assets			$	22					$	( 1 )					$	—					$	21
Derivative liabilities			( 1 )						1						—						—
Total foreign exchange contracts			$	21					$	—					$	—					$	21
Commodity contracts:
Derivative assets			$	4,365					$	( 2,992 )					$	( 168 )					$	1,205
Derivative liabilities			( 3,197 )						2,992						61						( 144 )
Total commodity contracts			$	1,168					$	—					$	( 107 )					$	1,061
Consumer Financing Program:
Derivative liabilities			$	( 203 )					$	—					$	—					$	( 203 )
Total derivative instruments			$	992					$	—					$	( 107 )					$	885

			Gross Amounts Not Offset in the Statement of Financial Position
(In millions)			Gross Amounts of Recognized Assets/Liabilities						Derivative Instruments						Cash Collateral (Held)/Posted						Net Amount
As of December 31, 2023
Interest rate contracts:
Derivative assets			$	12					$	( 8 )					$	—					$	4
Derivative liabilities			( 8 )						8						—						—
Total interest rate contracts			4						—						—						4
Foreign exchange contracts:
Derivative assets			$	5					$	( 5 )					$	—					$	—
Derivative liabilities			( 9 )						5						—						( 4 )
Total foreign exchange contracts			$	( 4 )					$	—					$	—					$	( 4 )
Commodity contracts:
Derivative assets			$	6,138					$	( 4,926 )					$	( 74 )					$	1,138
Derivative liabilities			( 5,356 )						4,926						145						( 285 )
Total commodity contracts			$	782					$	—					$	71					$	853
Consumer Financing Program:
Derivative liabilities			$	( 134 )					$	—					$	—					$	( 134 )
Total derivative instruments			$	648					$	—					$	71					$	719

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Impact of Derivative Instruments on the Statement of Operations

Unrealized gains and losses associated with changes in the fair value of derivative instruments that are not accounted for as cash flow hedges are reflected in current period results of operations.

The following tables summarize the pre-tax effects of economic hedges that have not been designated as cash flow hedges or fair value hedges and trading activity on the Company's statement of operations. The effect of foreign exchange and commodity hedges is included within revenues and cost of operations. The effect of the interest rate contracts is included within interest expense. The effect of the Consumer Financing Program is included in other income, net.

			Year Ended December 31,
(In millions)			2024						2023						2022
Unrealized mark-to-market results
Reversal of previously recognized unrealized losses/(gains) on settled positions related to economic hedges (a)			$	106					$	( 1,734 )					$	( 1,232 )
Reversal of acquired loss positions related to economic hedges			5						20						2
Net unrealized gains/(losses) on open positions related to economic hedges			95						( 1,149 )						2,478
Total unrealized mark-to-market gains/(losses) for economic hedging activities			206						( 2,863 )						1,248
Reversal of previously recognized unrealized (gains)/losses on settled positions related to trading activity			( 1 )						13						13
Net unrealized gains/(losses) on open positions related to trading activity			2						25						( 17 )
Total unrealized mark-to-market gains/(losses) for trading activity			1						38						( 4 )
Total unrealized gains/(losses) - commodities and foreign exchange			$	207					$	( 2,825 )					$	1,244

(a) December 31, 2024 balance includes $ 37 million related to derivative contracts that were elected as NPNS on October 1, 2024 and are no longer valued at fair value on a recurring basis

			Year Ended December 31,
(In millions)			2024						2023						2022
Total impact to statement of operations - interest rate contracts			$	3					$	4					$	—
Unrealized (losses)/gains included in revenues - commodities			$	( 2 )					$	182					$	( 87 )
Unrealized gains/(losses) included in cost of operations - commodities			186						( 2,988 )						1,315
Unrealized gains/(losses) included in cost of operations - foreign exchange			23						( 19 )						16
Total impact to statement of operations - commodities and foreign exchange			$	207					$	( 2,825 )					$	1,244
Total impact to statement of operations - Consumer Financing Program			$	( 14 )					$	( 16 )					$	—

The reversals of acquired loss/(gain) positions were valued based upon the forward prices on the acquisition date. The roll-off amounts were offset by realized gains or losses at the settled prices and are reflected in revenue or cost of operations during the same period.

The gains from open economic hedge positions of $ 95 million for the year ended December 31, 2024 was primarily the result of an increase in the value of forward positions as a result of increases in natural gas and power prices in the East.

The loss from open economic hedge positions of $ 1.1 billion for the year ended December 31, 2023 was primarily the result of a decrease in the value of forward positions as a result of decreases in natural gas and power prices in the East and West.

The gains from open economic hedge positions of $ 2.5 billion for the year ended December 31, 2022 was primarily the result of an increase in the value of forward positions as a result of increases in natural gas and power prices.

Credit Risk Related Contingent Features

Certain of the Company's hedging and trading agreements contain provisions that entitle the counterparty to demand that the Company post additional collateral if the counterparty determines that there has been deterioration in the Company's credit quality, generally termed “adequate assurance” under the agreements, or require the Company to post additional collateral if there were a downgrade in the Company's credit rating. The collateral potentially required for contracts with adequate assurance clauses that are in net liability positions as of December 31, 2024 was $ 589 million. The Company is also a party to certain

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marginable agreements under which it has a net liability position, but the counterparty has not called for the collateral due, which was approximately $ 54 million as of December 31, 2024. In the event of a downgrade in the Company's credit rating and if called for by the counterparty, $ 10 million of additional collateral would be required for all contracts with credit rating contingent features as of December 31, 2024.

See Note 5, Fair Value of Financial Instruments, for discussion regarding concentration of credit risk.

Inventory consisted of:

			As of December 31,
(In millions)			2024						2023
Coal			$	194					$	178
Natural gas			126						189
Fuel oil			8						8
Finished goods			79						164
Spare parts			71						68
Total Inventory			$	478					$	607

The Company's major classes of property, plant, and equipment were as follows:

			As of December 31,												Depreciable
(In millions)			2024						2023						Lives
Facilities and equipment			$	1,972					$	1,918					1 - 40 years
Land and improvements			255						256
Software			582						471						5 years
Hardware and office equipment and furnishings			278						261						2 - 10 years
Construction in progress			442						152
Total property, plant, and equipment			3,529						3,058
Accumulated depreciation			( 1,508 )						( 1,295 )
Net property, plant, and equipment			$	2,021					$	1,763

Depreciation expense of property, plant and equipment recorded during the years ended December 31, 2024, 2023 and 2022 was $ 271 million, $ 257 million and $ 291 million, respectively.

The Company leases generating facilities, land, office and equipment, railcars, fleet vehicles and storefront space at retail stores. Operating leases with an initial term greater than twelve months are recognized as right-of-use assets and lease liabilities in the consolidated balance sheets. The Company made an accounting policy election, as permitted by ASC 842, for all asset classes not to recognize right-of-use assets and lease liabilities in the consolidated balance sheets for its short-term leases, which are leases that have a lease term of twelve months or less. For the initial measurement of lease liabilities, the discount rate that the Company uses is either the rate implicit in the lease, if known, or its incremental borrowing rate, which is the rate of interest that the Company would have to pay to borrow, on a collateralized basis, over a similar term an amount equal to the payments for the lease. The Company recognizes lease expense for all operating leases on a straight-line basis over the lease term. In the future, should another systematic basis become more representative of the pattern in which the lessee expects to consume the remaining economic benefit of the right-of-use asset, the Company will use that basis for lease expense.

The Company considers a contract to be or to contain a lease when both of the following conditions apply: 1) an asset is either explicitly or implicitly identified in the contract and 2) the contract conveys to the Company the right to control the use of the identified asset for a period of time. The Company has the right to control the use of the identified asset when the Company has both the right to obtain substantially all the economic benefits from the use of the identified asset and the right to direct how and for what purpose the identified asset is used throughout the period of use.

Lease payments are typically fixed and payable on a monthly, quarterly, semi-annual or annual basis. Lease payments under certain agreements may escalate over the lease term either by a fixed percentage or a fixed dollar amount. Certain leases

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may provide for variable lease payments in the form of payments based on unit availability, usage, a percentage of sales from the location under lease, or index-based (e.g., the U.S. Consumer Price Index) adjustments to lease payments. The Company has no leases which contain residual value guarantees provided by the Company as a lessee.

Lease Cost:

			For the Year Ended December 31,
(In millions)			2024						2023						2022
Finance lease cost			$	9					$	8					$	4
Amortization of right-of-use assets			8						7						4
Interest on lease liabilities			1						1						—
Operating lease cost			89						93						85
Short-term lease cost			32						42						7
Variable lease cost			91						91						86
Sublease income			—						( 2 )						( 2 )
Total lease cost			$	221					$	232					$	180

Other information:

			For the Year Ended December 31,
(In millions)			2024						2023						2022
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases			$	190					$	195					$	183
Financing cash flows from finance leases			8						7						5
Right-of-use assets obtained in exchange for new finance lease liabilities			13						17						3
Right-of-use assets obtained in exchange for new operating lease liabilities			69						52						28

Lease Term and Discount Rate for leases:

			December 31, 2024						December 31, 2023
Finance leases:
Weighted average remaining lease term (in years)			2.7						2.9
Weighted average discount rate			6.26		%				4.87		%
Operating leases:
Weighted average remaining lease term (in years)			5.4						3.6
Weighted average discount rate			6.23		%				6.00		%

As of December 31, 2024, annual payments based on the maturities of the Company's operating leases are expected to be as follows:

			In millions
2025			$	85
2026			40
2027			35
2028			27
2029			18
Thereafter			87
Total undiscounted lease payments			$	292
Less: present value adjustment			( 109 )
Total discounted lease payments			$	183

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2024 Impairment Losses

During the fourth quarter of 2024, the Company completed its annual budget and analyzed the corresponding impact on estimated cash flows associated with its long-lived assets. The fair value of the assets was determined using an income approach by applying a discounted cash flow methodology to the long-term budget for each facility. The income approach utilized estimates of after-tax cash flows, which were Level 3 fair value measurements, and included key inputs such as forecasted power prices, fuel costs, operating and maintenance costs, plant investment capital expenditures and discount rates.

As a result of the evaluation performed, the Company recorded impairment losses of $ 7 million and $ 14 million related to its equity method investments in Gladstone and property plant and equipment and leases in the West/Services/Other segment, respectively. For further discussion of the Gladstone investment, see Note 16, Investments Accounted for by the Equity Method and Variable Interest Entities .

Other Impairments — The Company recorded impairment losses related to excess SO 2 allowances of $ 7 million in the Texas segment and goodwill impairment losses of $ 15 million in the West/Services/Other segment.

2023 Impairment Losses

During the fourth quarter of 2023, the Company completed its annual budget and analyzed the corresponding impact on estimated cash flows associated with its long-lived assets. The fair value of the assets was determined using an income approach by applying a discounted cash flow methodology to the long-term budget for each facility. The income approach utilized estimates of after-tax cash flows, which were Level 3 fair value measurements, and included key inputs such as forecasted power prices, fuel costs, operating and maintenance costs, plant investment capital expenditures and discount rates.

Gladstone — The Company recorded impairment losses of $ 102 million on its equity method investment in Gladstone within the West/Services/Other segment as a result of changes in the long-term outlook of the Gladstone facility, prompted by evolving energy policy conditions in Australia and an assessment of the long-term operational landscape of the facility, which concluded with the annual budget process. For further discussion of the Gladstone investment, see Note 16, Investments Accounted for by the Equity Method and Variable Interest Entities .

Other Impairments — The Company additionally recorded impairment losses related to property plant and equipment and leases of $ 2 million, $ 4 million and $ 20 million in the Texas, East and West/Services/Other segments, respectively.

2022 Impairment Losses

Astoria Redevelopment Impairment — During the third quarter of 2022, the Company entered into a purchase and sale agreement for the sale of the land and related assets at the Astoria generating site and the planned withdrawal and cancellation of its proposed Astoria redevelopment project. As a result, the Company impaired $ 43 million of Astoria project spend in the East segment. For further discussion of the transaction, see Note 4, Acquisitions and Dispositions .

PJM Asset Impairments — During the second quarter of 2022, the results of the PJM Base Residual Auction for the 2023/2024 delivery year were released leading the Company to revise its long-term view of certain facilities and announce the planned retirement of the Joliet generating facility. The Company considered the near-term retirement date of Joliet and the decline in PJM capacity prices to be a trigger for impairment and performed impairment tests on the PJM generating assets and the goodwill associated with Midwest Generation. The Company measured the impairment losses on the PJM generating assets and Midwest Generation goodwill as the difference between the carrying amount and the fair value of the PJM generating assets and Midwest Generation reporting unit, respectively. Fair values were determined using an income approach in which the Company applied a discounted cash flow methodology to the long-term budgets for the plants and reporting unit. Significant inputs impacting the income approach include the Company's long-term view of capacity and fuel prices, projected generation, the physical and economic characteristics of each plant and the reporting unit as a whole, and the discount rate applied to the after-tax cash flow projections. Impairment losses of $ 20 million and $ 130 million were recorded in the East segment on the PJM generating assets and Midwest Generation goodwill, respectively.

Other Impairments — The Company additionally recorded impairment losses of $ 13 million in the East segment.

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Goodwill

The following table presents the changes in goodwill for the years ended December 31, 2024 and 2023 based on the Company's reportable segments:

(in millions)			Texas						East						West/Services/Other						Vivint Smart Home						Total
Balance as of January 1, 2023			$	710					$	723					$	217					$	—					$	1,650
Goodwill resulted from the acquisition of Vivint			—						—						—						3,494						3,494
Asset sales			( 67 )						( 2 )						—						—						( 69 )
Foreign currency translation adjustments			—						—						4						—						4
Balance as of December 31, 2023			$	643					$	721					$	221					$	3,494					$	5,079
Impairment			—						—						( 15 )						—						( 15 )
Sale of Airtron			—						—						( 43 )						—						( 43 )
Foreign currency translation adjustments			—						—						( 10 )						—						( 10 )
Balance as of December 31, 2024			$	643					$	721					$	153					$	3,494					$	5,011

Intangible Assets

The Company's intangible assets as of December 31, 2024, primarily reflect intangible assets established with the acquisitions of various companies, including Vivint Smart Home, Direct Energy, other retail acquisitions and Texas Genco. Intangible assets are comprised of the following:

• Emission Allowances — These intangibles primarily consist of SO 2 emission allowances, including those established with the 2006 acquisition of Texas Genco, RGGI emission credits and California carbon allowances. These emission allowances are held-for-use and are amortized to cost of operations based on units of production.

• Customer and supply contracts — These intangibles include the fair value at the acquisition date of in-market and out-of-market customer and supply contracts from the acquisition of Direct Energy and are amortized to revenue and cost of operations, respectively, based upon the fair market value, as of the acquisition date, for each delivery month.

• Customer relationships — These intangibles represent the fair value at the acquisition date of acquired businesses' customer base from the acquisition of Vivint, Direct Energy and other acquisitions. Customer relationships are amortized to depreciation and amortization expense based on the expected discounted future net cash flows by year.

• Marketing partnerships — These intangibles represent the fair value at the acquisition date of existing agreements with marketing vendors and loyalty and affinity partners for customer acquisition. Marketing partnerships are amortized to depreciation and amortization expense based on the expected discounted future net cash flows by year.

• Technology — These intangibles represent the fair value at the acquisition date of developed technology for Vivint Smart Home integrated software and products. Technology is amortized to depreciation and amortization expense, ratably based on the expected discounted future net cash flows by year.

• Trade names — These intangibles are amortized to depreciation and amortization expense on a straight-line basis.

• Other — These intangibles primarily include renewable energy certificates. RECs are retired, as required, for the applicable compliance period. RECs are expensed to cost of operations based on NRG’s customer usage. Other also included in-market nuclear fuel contracts established from the Texas Genco acquisition in 2006 which were amortized to cost of operations over expected volumes over the life of each contract, costs to extend the operating license for STP Units 1 and 2 and intellectual property related to Goal Zero, which was amortized to depreciation and amortization expense.

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The following tables summarize the components of NRG's intangible assets:

(In millions)
Year Ended December 31, 2024			Emission Allowances						Customer and Supply Contracts												Customer Relationships						Marketing Partnerships						Technology						Trade Names						Other (a)						Total
January 1, 2024			$	628					$	609											$	3,464					$	295					$	860					$	841					$	224					$	6,921
Purchases			22						—												—						—						—						—						497						519
Acquisition of businesses (b)			—						—												35						—						—						—						—						35
Usage/Sales/Retirements/Transfers			( 19 )						—												—						—						—						—						( 461 )						( 480 )
Write-off of fully amortized balances			—						—												( 146 )						—						—						( 11 )						—						( 157 )
Sale of Airtron (c)			—						—												( 255 )						—						—						( 24 )						—						( 279 )
Other			( 6 )						( 3 )												( 5 )						( 1 )						1						( 5 )						—						( 19 )
December 31, 2024			625						606												3,093						294						861						801						260						6,540
Less accumulated amortization			( 538 )						( 399 )												( 1,555 )						( 193 )						( 457 )						( 443 )						( 47 )						( 3,632 )
Net carrying amount			$	87					$	207											$	1,538					$	101					$	404					$	358					$	213					$	2,908

(a) RECs are not subject to amortization and had a carrying value of $ 213 million

(b) The weighted average amortization period for total amortizable intangible assets is approximately 5 years

(c) Includes $ 81 million of intangibles that were amortized

(In millions)
Year Ended December 31, 2023			Emission Allowances						Customer and Supply Contracts												Customer Relationships						Marketing Partnerships						Technology						Trade Names						Other (a)						Total
January 1, 2023			$	624					$	635											$	1,730					$	284					$	—					$	679					$	292					$	4,244
Purchases			10						—												—						—						—						—						465						475
Acquisition of businesses (b)			—						—												1,773						10						860						160						—						2,803
Usage/Sales/Retirements			—						—												—						—						—						—						( 474 )						( 474 )
Write-off of fully amortized balances			( 1 )						( 28 )												( 43 )						—						—						—						—						( 72 )
Sale of STP (c)			—						—												—						—						—						—						( 59 )						( 59 )
Other			( 5 )						2												4						1						—						2						—						4
December 31, 2023			628						609												3,464						295						860						841						224						6,921
Less accumulated amortization			( 533 )						( 328 )												( 1,300 )						( 170 )						( 230 )						( 401 )						( 32 )						( 2,994 )
Net carrying amount			$	95					$	281											$	2,164					$	125					$	630					$	440					$	192					$	3,927

(a) RECs are not subject to amortization and had a carrying value of $ 177 million

(b) The weighted average amortization period for total amortizable intangible assets is approximately 10 years

(c) Includes $ 47 million of intangibles that were amortized

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The following table presents NRG's amortization of intangible assets for each of the past three years:

			Years Ended December 31,
(In millions)			2024						2023						2022
Emission allowances			$	5					$	6					$	6
Customer and supply contracts			71						121						141
Customer relationships			476						556						269
Marketing partnerships			23						24						23
Technology			227						230						—
Trade names			59						60						47
Other (a)			15						4						4
Total amortization			$	876					$	1,001					$	490

(a) For the year ended December 31, 2024, 2023 and 2022, other intangibles amortized to depreciation and amortization expense were $ 15 million, de minimis and $ 4 million, respectively

The following table presents estimated amortization of NRG's intangible assets as of December 31, 2024 for each of the next five years:

(In millions)
Year Ended December 31,			Emission Allowances												Customer and Supply Contracts						Customer Relationships						Marketing Partnerships						Technology						Trade Names												Total
2025			$	15											$	50					$	361					$	23					$	176					$	45											$	670
2026			16												52						289						23						130						37												547
2027			19												30						220						23						89						37												418
2028			20												12						177						15						9						37												270
2029			12												13						137						5						—						37												204

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Long-term debt and finance leases consisted of the following:

			As of December 31,
(In millions, except rates)			2024						2023						Interest rate %
Recourse debt:
Senior Notes, due 2027			$	—					$	375					6.625
Senior Notes, due 2028			821						821						5.750
Senior Notes, due 2029			733						733						5.250
Senior Notes, due 2029			500						500						3.375
Senior Notes, due 2029			798						—						5.750
Senior Notes, due 2031			1,030						1,030						3.625
Senior Notes, due 2032			480						480						3.875
Senior Notes, due 2033			925						—						6.000
Senior Notes, due 2034			950						—						6.250
Convertible Senior Notes, due 2048 (a)			232						575						2.750
Senior Secured First Lien Notes, due 2024			—						600						3.750
Senior Secured First Lien Notes, due 2025			500						500						2.000
Senior Secured First Lien Notes, due 2027			900						900						2.450
Senior Secured First Lien Notes, due 2029			500						500						4.450
Senior Secured First Lien Notes, due 2033			740						740						7.000
Term Loan B, due 2031			1,317						—						SOFR + 1.750
Tax-exempt bonds			466						466						1.250 - 4.750
Subtotal recourse debt			10,892						8,220
Non-recourse debt:
Vivint Senior Notes, due 2029			—						800						5.750
Vivint Senior Secured Notes, due 2027			—						600						6.750
Vivint Senior Secured Term Loan, due 2028			—						1,320						SOFR + 3.510
Subtotal all Vivint non-recourse debt			—						2,720
Subtotal long-term debt (including current maturities)			10,892						10,940
Finance leases			14						19						various
Subtotal long-term debt and finance leases (including current maturities)			10,906						10,959
Less current maturities			( 996 )						( 620 )
Less debt issuance costs			( 86 )						( 60 )
Discounts			( 12 )						( 146 )
Total long-term debt and finance leases			$	9,812					$	10,133

(a) As of the ex-dividend date of February 3, 2025, the Convertible Senior Notes were convertible at a price of $ 40.78 , which is equivalent to a conversion rate of approximately 24.5222 shares of common stock per $1,000 principal amount of Convertible Senior Notes

Debt includes the following discounts:

						As of December 31,
(In millions)						2024						2023
Senior Secured First Lien Notes, due 2025, 2027, 2029 and 2033						$	( 10 )					$	( 10 )
Term Loan B, due 2031						( 2 )						—
Vivint Senior Notes, due 2029						—						( 103 )
Vivint Senior Secured Notes, due 2027						—						( 12 )
Vivint Senior Secured Term Loan, due 2028						—						( 21 )
Total discounts						$	( 12 )					$	( 146 )

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Consolidated Annual Maturities

As of December 31, 2024, annual payments based on the maturities of NRG’s debt and finance leases are expected to be as follows:

			(In millions)
2025			$	996
2026			18
2027			916
2028			894
2029			2,544
Thereafter			5,538
Total			$	10,906

Recourse Debt

Senior Notes

Issuance of 2029 Senior Notes, 2033 Senior Notes and 2034 Senior Notes

On October 30, 2024, the Company issued $ 1.9 billion in aggregate principal amount of senior unsecured notes, consisting of (i) $ 925 million aggregate principal amount of 6.000 % senior unsecured notes due 2033 (the “2033 Notes”) and (ii) $ 950 million aggregate principal amount of 6.250 % senior unsecured notes due 2034 (the “2034 Notes” and, together with the 2033 Notes, the “Notes”). In addition, on October 30, 2024, the Company issued $ 798 million aggregate principal amount of 5.750 % senior unsecured notes due 2029 (the “New NRG 5.750 % Senior Notes due 2029”) in connection with the Company’s previously announced offer to exchange. The Notes and the New NRG 5.750 % Senior Notes due 2029 are senior unsecured obligations of the Company and are guaranteed by certain of its subsidiaries that guarantee indebtedness under the Senior Credit Facility. Interest on the New NRG 5.750 % Senior Notes due 2029 is paid semi-annually beginning on January 15, 2025 until the maturity date of July 15, 2029. Interest on the 2033 Notes is paid semi-annually beginning on February 1, 2025 until the maturity date of February 1, 2033. Interest on the 2034 Notes is paid semi-annually beginning on May 1, 2025 until the maturity date of November 1, 2034.

On October 30, 2024, the Company used the net proceeds from the offering of the Notes, together with the net proceeds of its new incremental term loan B in an aggregate principal amount of $ 450 million, to pay the cash tender price for any and all of APX Group, Inc.’s 6.750 % Senior Secured Notes due 2027 and to repay APX Group, Inc.’s secured term loans in an outstanding aggregate principal amount of approximately $ 1.3 billion under its senior secured credit agreement. In addition, on October 31, 2024, the Company used the net proceeds from the offering of the Notes and cash on hand to redeem all of its outstanding 6.625 % Senior Notes due 2027, of which $ 375 million aggregate principal amount was outstanding. Any remaining net proceeds from the offering was used to pay the transaction fees, expenses and premiums, to refinance outstanding debt and for general corporate purposes.

Senior Note Redemptions

During the year ended December 31, 2024, the Company redeemed $ 375 million in aggregate principal amount of its 6.625 % Senior Notes due 2027, at a redemption price equal to 100.000 % for $ 382 million, which included the payment of $ 7 million of accrued interest, using the net proceeds from the offering of the Notes and cash on hand. In connection with the redemption, the Company wrote-off $ 1 million of previously deferred financing costs and other fees, which was recorded to loss on debt extinguishment.

3.750 % Senior Secured First Lien Note due 2024 Repayment

On June 17, 2024, the Company repaid $ 600 million in aggregate principal amount of its 3.750 % Senior Secured First Lien Notes due 2024.

Senior Credit Facility

Term Loan B Incurrence

On April 16, 2024, the Company, as borrower, and certain of its subsidiaries, as guarantors, entered into the Eighth Amendment to the Credit Agreement in order to (i) establish the Existing Term Loan B Facility with borrowings of $ 875 million in aggregate principal amount and the Existing Term Loans and (ii) make certain other modifications to the Credit Agreement as set forth therein. The proceeds from the Existing Term Loans were used to repay a portion of the Company’s Convertible Senior Notes, all of the Company’s 3.750 % senior secured first lien notes due 2024 and for general corporate purposes.

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On October 30, 2024, the Company, as borrower, and certain of its subsidiaries, as guarantors, entered into the Eleventh Amendment to the Credit Agreement in order to include the Incremental Term Loan B Facility in an aggregate principal amount of $ 450 million and the Incremental Term Loans, which Incremental Term Loan B Facility is fungible for U.S. federal tax purposes with the Existing Term Loan B Facility. The proceeds from the Incremental Term Loans, together with the proceeds of the Notes, were used to repay all loans and other amounts outstanding under APX’s senior secured credit agreement and to pay the cash tender price for any and all of APX Group, Inc.’s 6.750 % Senior Secured Notes due 2027. The terms of the Incremental Term Loan B Facility (including pricing) are identical to those applicable to the Existing Term Loan B Facility, and the Incremental Term Loans constitute the same class of term loans as the Company’s Existing Term Loans.

On November 26, 2024, the Company, as borrower, entered into the Twelfth Amendment to the Credit Agreement in order to (i) reprice both the Existing Term Loan B Facility and the Incremental Term Loan B Facility and (ii) make certain other modifications to the Credit Agreement as set forth therein.

Following the effectiveness of the Twelfth Amendment, at the Company’s election, the Existing Term Loans and the Incremental Term Loans bear interest at a rate per annum equal to either (1) a fluctuating rate equal to the highest of (A) the rate published by the Federal Reserve Bank of New York in effect on such day, plus 0.50 %, (B) the rate of interest per annum publicly announced from time to time by The Wall Street Journal as the “Prime Rate” in the United States, and (C) a rate of one-month Term SOFR (as defined in the Credit Agreement) (after giving effect to any floor applicable to Term SOFR) plus 1.00 %, in each case, plus a margin of 0.75 % or (2) Term SOFR (as defined in the Credit Agreement) (which shall not be less than 0.00 %) for a one-, three- or six-month interest period (or such other period as agreed to by the Agent and the lenders, as selected by the Company), plus a margin of 1.75 %.

The Existing Term Loan B Facility and the Incremental Term Loan B Facility are guaranteed by each of the Company’s subsidiaries that guarantee the Company’s Revolving Credit Facility and are secured on a first lien basis by substantially all of the Company’s and such subsidiaries’ assets, in each case, subject to certain customary exceptions and limitations set forth in the Credit Agreement.

The Existing Term Loans and the Incremental Term Loans have a final maturity date of April 16, 2031 and amortize at a rate of 1 % per annum in equal quarterly installments (subject to any adjustments to such amortization payments to ensure that such Incremental Term Loans are fungible for U.S. federal tax purposes with the Existing Term Loans). If an event of default occurs under the Existing Term Loan B Facility or the Incremental Term Loan B Facility, the entire principal amount outstanding thereunder, together with all accrued unpaid interest and other amounts owing in respect thereof, may be declared immediately due and payable, subject, in certain instances, to the expiration of applicable cure periods. The Existing Term Loan B Facility and the Incremental Term Loan B Facility also provide for customary asset sale mandatory prepayments, reporting covenants and negative covenants governing dividends, investments, indebtedness, and other matters that are customary for similar term loan B facilities.

On December 20, 2024, the Company, as borrower, entered into the Thirteenth Amendment to the Credit Agreement to (i) add APX Group, Inc. as an additional borrower of the loans under the Credit Agreement on a joint and several basis with the Company and (ii) make certain other modifications to the Credit Agreement as set forth therein.

Revolving Credit Facility

On April 22, 2024, the Company, as borrower, and certain of its subsidiaries, as guarantors, entered into the Ninth Amendment to extend the maturity date of a portion of the revolving commitments thereunder to February 14, 2028.

On October 30, 2024, the Company, as borrower, and certain of its subsidiaries, as guarantors, entered into the Tenth Amendment to (i) extend the maturity date of its revolving credit facility to October 30, 2029 and (ii) make certain other amendments to the Credit Agreement as set forth therein.

As of December 31, 2024, there were no outstanding borrowings and there were $ 477 million in letters of credit issued under the Revolving Credit Facility.

2048 Convertible Senior Notes

Accounting for Convertible Senior Notes — Beginning in 2022, the Company no longer records the conversion feature of its convertible senior notes in equity. Instead, the Company combined the previously separated equity component with the liability component, which together is now classified as debt, thereby eliminating the subsequent amortization of the debt discount as interest expense.

Modification to Convertible Senior Notes — In 2022, the Company irrevocably elected to eliminate the right to settle conversions only in shares of the Company's common stock, such that any conversion after such date, the Company will pay cash per $1,000 principal amount and will settle in cash or a combination of cash and the Company’s common stock for the remainder, if any, of the Company’s conversion obligation in excess of the aggregate principal amount.

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Convertible Senior Notes Features — As of December 31, 2024, the Convertible Senior Notes are convertible, under certain circumstances, into cash or a combination of cash and the Company’s common stock at a price of $ 40.94 per common share, which is the equivalent to a conversion rate of approximately 24.4241 shares of common stock per $1,000 principal amount of Convertible Senior Notes. As of December 31, 2023, the Convertible Senior Notes were convertible at a price of $ 41.83 per common share, which is equivalent to a conversion rate of approximately 23.9079 shares of common stock per $1,000 principal amount of Convertible Senior Notes. The settlement method is at the Company’s election. The net carrying amounts of the Convertible Senior Notes as of December 31, 2024 and December 31, 2023 were $ 231 million and $ 572 million, respectively. The Convertible Senior Notes mature on June 1, 2048, unless earlier repurchased, redeemed or converted in accordance with their terms.

The Convertible Senior Notes are convertible at the option of the holders only upon the occurrence of certain events and during certain periods, including, among others, during any calendar quarter (and only during such calendar quarter) if the last reported sales price per share of the Company’s common stock exceeded 130 % of the conversion price for each of at least 20 trading days, whether or not consecutive, during the 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter (the “Common Stock Sale Price Condition”). As of January 1, 2025, the Company’s Convertible Senior Notes are convertible during the quarterly period ending March 31, 2025 due to the satisfaction of the Common Stock Sale Price Condition. In addition, the Convertible Senior Notes are also convertible during specified periods as follows:

• from December 1, 2024 until the close of business on the second scheduled trading day immediately before June 1, 2025; and

• from December 1, 2047 until the close of business on the second scheduled trading day immediately before the maturity date.

All conversions with a conversion date that occurs within the specific periods above will be settled after such period pursuant to the terms of the Convertible Senior Notes indenture.

The following table details the interest expense recorded in connection with the Convertible Senior Notes:

			For the years ended December 31,
(In millions, except percentages)			2024						2023						2022
Contractual interest expense			$	9					$	16					$	16
Amortization of discount and deferred finance costs			1						2						1
Total			$	10					$	18					$	17
Effective Interest Rate			3.08		%				3.18		%				3.01		%

Convertible Senior Notes Repurchases

During the year ended December 31, 2024, the Company completed repurchases of a portion of the Convertible Senior Notes using cash on hand and a portion of the proceeds from the Term Loans, as detailed in the table below. For the year ended December 31, 2024, a $ 260 million loss on debt extinguishment was recorded in connection with the repurchases below.

(In millions, except percentages)
Settlement Period						Principal Repurchased						Cash Paid (a)						Average Repurchase Percentage
March 2024						$	92					$	151					162.356 %
April 2024						251						452						179.454 %
Total Repurchases						$	343					$	603

(a) Includes accrued interest of $ 1 million and $ 2 million for the March and April repurchases, respectively

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Capped Call Options

During the second quarter of 2024, the Company entered into privately negotiated capped call transactions with certain counterparties (the “Capped Calls”) to effectively lock in a conversion premium of $ 257 million on the remaining $ 232 million in aggregate principal amount of the Convertible Senior Notes. The option price of $ 257 million was incurred when the Company entered into the Capped Calls, which will be payable upon the earlier of settlement and expiration of the applicable Capped Calls. For further discussion see Note 15, Capital Structure.

Senior Notes Early Redemption

As of December 31, 2024, the Company had the following outstanding issuances of senior notes with an early redemption feature, or Senior Notes:

i. 5.750 % senior notes, issued December 7, 2017 and due January 15, 2028, or the 2028 Senior Notes;

ii. 5.250 % senior notes, issued May 24, 2019 and due June 15, 2029, or the 5.250 % 2029 Senior Notes;

iii. 3.375 % senior notes, issued December 2, 2020 and due February 15, 2029, or the 3.375 % 2029 Senior Notes;

iv. 5.750 % senior notes, issued October 30, 2024 and due July 15, 2029, or the 5.750 % 2029 Senior Notes;

v. 3.625 % senior notes, issued December 2, 2020 and due February 15, 2031, or the 2031 Senior Notes;

vi. 3.875 % senior notes, issued August 23, 2021 and due February 15, 2032, or the 2032 Senior Notes;

vii. 6.000 % senior notes, issued October 30, 2024 and due February 1, 2033, or the 2033 Senior Notes; and

viii. 6.250 % senior notes, issued October 30, 2024 and due November 1, 2034, or the 2034 Senior Notes.

The indentures and the forms of notes provide, among other things, that the Senior Notes will be senior unsecured obligations of the Company. The indentures also provide for customary events of default, which include, among others: nonpayment of principal or interest; breach of other covenants in the indentures; defaults in failure to pay certain other indebtedness; the rendering of judgments to pay certain amounts of money against the Company and certain of its subsidiaries; the failure of certain guarantees to be enforceable; and certain events of bankruptcy or insolvency. Generally, if an event of default occurs and continues, the trustee or the holders of at least 25 % or 30 % (depending on the series of Senior Notes) in principal amount of the then-outstanding series of Senior Notes may declare all of the Senior Notes of such series to be due and payable immediately. The terms of the indentures contain certain restrictions on incurring secured debt and consolidating, merging or transferring all or substantially all of the Company’s assets. Interest is payable semi-annually on the Senior Notes until their maturity dates.

2028 Senior Notes

The Company may redeem some or all of the 2028 Senior Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed up to the redemption date:

Redemption Period			Redemption Percentage
January 15, 2025 to January 14, 2026			100.958		%
January 15, 2026 and thereafter			100.000		%

5.250 % 2029 Senior Notes

The Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed up to the redemption date:

Redemption Period			Redemption Percentage
June 15, 2024 to June 14, 2025			102.625		%
June 15, 2025 to June 14, 2026			101.750		%
June 15, 2026 to June 14, 2027			100.875		%
June 15, 2027 and thereafter			100.000		%

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3.375 % 2029 Senior Notes

The Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed up to the redemption date:

Redemption Period			Redemption Percentage
February 15, 2025 to February 14, 2026			100.844		%
February 15, 2026 and thereafter			100.000		%

5.750 % 2029 Senior Notes

The Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed up to the redemption date:

Redemption Period			Redemption Percentage
July 15, 2024 to July 14, 2025			102.875		%
July 15, 2025 to July 14, 2026			101.438		%
July 15, 2026 and thereafter			100.000		%

2031 Senior Notes

At any time prior to February 15, 2026, the Company may redeem all or a part of the 2031 Senior Notes, at a redemption price equal to 100 % of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1 % of the principal amount of the note; or (ii) the excess of the present value of 101.813 % of the note, plus interest payments due on the note through February 15, 2026 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50 % over the principal amount of the note. In addition, on or after February 15, 2026, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed up to the redemption date:

Redemption Period			Redemption Percentage
February 15, 2026 to February 14, 2027			101.813		%
February 15, 2027 to February 14, 2028			101.208		%
February 15, 2028 to February 14, 2029			100.604		%
February 15, 2029 and thereafter			100.000		%

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2032 Senior Notes

At any time prior to February 15, 2027, the Company may redeem all or a part of the 2032 Senior Notes, at a redemption price equal to 100 % of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1 % of the principal amount of the notes; or (ii) the excess of (A) the present value of (1) the redemption price of the note at February 15, 2027 (such redemption price being set forth in the table appearing below in the column “Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)” unless the Sustainability Performance Target has been satisfied in respect of the year ended December 31, 2025 and the Company has provided confirmation thereof to the trustee together with a related confirmation by the External Verifier by the date that is at least 15 days prior to August 15, 2026 in which case the redemption price shall be as set forth in the column “Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)”) plus (2) interest payments due on the note through February 15, 2027 (excluding accrued but unpaid interest to the redemption date) computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50 %, over (B) the principal amount of the note. In addition, on or after February 15, 2027, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table during the twelve-month period beginning on February 15 of the years indicated below, plus accrued and unpaid interest on the notes redeemed up to the redemption date:

Year			Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)						Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)
2027			101.938		%				102.188		%
2028			101.292		%				101.458		%
2029			100.646		%				100.729		%
2030 and thereafter			100.000		%				100.000		%

2033 Senior Notes

At any time prior to November 1, 2027, the Company may redeem all or a part of the 2033 Senior Notes, at a redemption price equal to 100 % of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1 % of the principal amount of the note; or (ii) the excess of the present value of 103.000 % of the note, plus interest payments due on the note through November 1, 2027 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50 % over the principal amount of the note. In addition, on or after November 1, 2027, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed up to the redemption date:

Redemption Period			Redemption Percentage
November 1, 2027 to October 31, 2028			103.000		%
November 1, 2028 to October 31, 2029			101.500		%
November 1, 2029 and thereafter			100.000		%

2034 Senior Notes

At any time prior to November 1, 2029, the Company may redeem all or a part of the 2034 Senior Notes, at a redemption price equal to 100 % of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1 % of the principal amount of the note; or (ii) the excess of the present value of 103.125 % of the note, plus interest payments due on the note through November 1, 2029 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50 % over the principal amount of the note. In addition, on or after November 1, 2029, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed up to the redemption date:

Redemption Period			Redemption Percentage
November 1, 2029 to October 31, 2030			103.125		%
November 1, 2030 to October 31, 2031			101.563		%
November 1, 2031 and thereafter			100.000		%

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Receivables Securitization Facilities

In 2020, NRG Receivables LLC, a bankruptcy remote, special purpose, indirect wholly owned subsidiary (“NRG Receivables”), entered into the Receivables Facility, subject to adjustments on a seasonal basis, with issuers of asset-backed commercial paper and commercial banks (the “Lenders”). The assets of NRG Receivables are first available to satisfy the claims of the Lenders before making payments on the subordinated note and equity issued by NRG Receivables. The assets of NRG Receivables are not available to the Company and its subsidiaries or creditors unless and until distributed by NRG Receivables. Under the Receivables Facility, certain indirect subsidiaries of the Company sell their accounts receivables to NRG Receivables, subject to certain terms and conditions. In turn, NRG Receivables grants a security interest in the purchased receivables to the Lenders as collateral for cash borrowings and issuances of letters of credit. Pursuant to the Performance Guaranty, the Company has guaranteed, for the benefit of NRG Receivables and the Lenders, the payment and performance by each indirect subsidiary of its respective obligations under the Receivables Facility. The accounts receivables remain on the Company’s consolidated balance sheet and any amounts funded by the Lenders to NRG Receivables will be reflected as short-term borrowings. Cash flows from the Receivables Facility are reflected as financing activities in the Company’s consolidated statements of cash flows. The Company continues to service the accounts receivables sold in exchange for a servicing fee.

In 2020, the Company entered into the Repurchase Facility related to the Receivables Facility. Under the Repurchase Facility, the Company could borrow up to $ 150 million, collateralized by a subordinated note issued by NRG Receivables to NRG Retail LLC in favor of the originating entities representing a portion of the balance of receivables sold to NRG Receivables under the Receivables Facility.

On June 21, 2024, NRG Receivables LLC (“NRG Receivables”), an indirect wholly-owned subsidiary of the Company, amended its existing Receivables Facility to, among other things, (i) extend the scheduled termination date to June 20, 2025, (ii) increase the aggregate commitments from $ 1.4 billion to $ 2.3 billion (adjusted seasonally) and (iii) add a new originator. The weighted average interest rate related to usage under the Receivables Facility as of December 31, 2024 was 0.776 %. As of December 31, 2024, there were no outstanding borrowings and there were $ 1.4 billion in letters of credit issued under the Receivables Facility.

Also on June 21, 2024, Direct Energy Services, LLC (in its capacity as additional originator, the “Additional Originator”) entered into a Joinder Agreement (the “Joinder Agreement”) to join as Additional Originator to the Receivables Sale Agreement, dated as of September 22, 2020, among Direct Energy, LP, Direct Energy Business, LLC, Green Mountain Energy Company, NRG Business Marketing, LLC, Reliant Energy Northeast LLC, Reliant Energy Retail Services, LLC, Stream SPE, Ltd., US Retailers LLC and XOOM Energy Texas, LLC, as originators, NRG Retail, as the servicer, and NRG Receivables (the “Receivables Sale Agreement”). Pursuant to the Joinder Agreement, the Additional Originator agrees to be bound by the terms of the Receivables Sale Agreement, will sell to NRG Receivables substantially all of its receivables for the sale of electricity, natural gas and/or related services and certain related rights (collectively, the “Receivables”) and in connection therewith have transferred to NRG Receivables the deposit accounts into which the proceeds of such Receivables are paid.

Concurrently with the amendments to the Receivables Facility, the Company and the originators thereunder terminated the existing uncommitted Repurchase Facility.

Tax Exempt Bonds

						As of December 31,
(In millions, except rates)						2024						2023						Interest Rate %
NRG Indian River Power 2020, tax exempt bonds, due 2040						$	57					$	57					1.250
NRG Indian River Power 2020, tax exempt bonds, due 2045						190						190						1.250
NRG Dunkirk 2020, tax exempt bonds, due 2042						59						59						4.250
City of Texas City, tax exempt bonds, due 2045						33						33						4.125
Fort Bend County, tax exempt bonds, due 2038						54						54						4.750
Fort Bend County, tax exempt bonds, due 2042						73						73						4.750
Total						$	466					$	466

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The Company's AROs are primarily related to the environmental obligations for mine reclamation, ash disposal, site closures, fuel storage facilities and future dismantlement of equipment on leased property. In addition, the Company has also identified conditional AROs for asbestos removal and disposal, which are specific to certain power generation operations.

The following table presents the balance of ARO obligations as of December 31, 2024 and 2023, along with the activity related to the Company's ARO obligations for the year ended December 31, 2024:

(In millions)															Total (a)
Balance as of December 31, 2023															$	407
Revisions in estimates for current obligations															6
Additions															6
Spending for current obligations															( 35 )
Accretion															25
Balance as of December 31, 2024															$	409

(a) Total accretion expense related to asset retirement obligations included in the consolidated statement of cash flows includes accretion and revisions in estimates for asset retirement liabilities on non-operating plants

NRG sponsors and operates defined benefit pension and other postretirement plans. NRG pension benefits are available to eligible non-union and union employees through various defined benefit pension plans. These benefits are based on pay, service history and age at retirement. Most pension benefits are provided through tax-qualified plans. NRG also provides postretirement health and welfare benefits for certain groups of employees. Cost sharing provisions vary by the terms of any applicable collective bargaining agreements.

NRG maintains three separate qualified pension plans, the NRG Pension Plan for Bargained Employees, the NRG Pension Plan and the Pension Plan for Employees of Direct Energy Marketing Limited (“DEML”). Participation in the NRG Pension Plan for Bargained Employees depends upon whether an employee is covered by a bargaining agreement. The NRG Pension Plan was frozen for non-union employees on December 31, 2018. In 2024, the Company commenced the termination process for the defined benefit component of the Pension Plan for Employees of DEML and expects to complete the transaction in 2025.

NRG expects to contribute $ 16 million to the Company's pension plans in 2025.

NRG Defined Benefit Plans

The annual net periodic benefit cost/(credit) related to NRG's pension and other postretirement benefit plans include the following components:

			Year Ended December 31,
			Pension Benefits
(In millions)			2024						2023						2022
Service cost benefits earned			$	3					$	5					$	7
Interest cost on benefit obligation			48						50						41
Expected return on plan assets			( 47 )						( 39 )						( 47 )
Amortization of unrecognized net loss			2						6						3
Curtailment and special termination benefits (income)/expense			( 6 )						( 1 )						14
Net periodic benefit cost			$	—					$	21					$	18

			Year Ended December 31,
			Other Postretirement Benefits
(In millions)			2024						2023						2022
Interest cost on benefit obligation			$	3					$	4					$	2
Amortization of unrecognized prior service cost			( 3 )						( 8 )						( 8 )
Amortization of unrecognized net loss			( 1 )						1						2
Net periodic benefit credit			$	( 1 )					$	( 3 )					$	( 4 )

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A comparison of the pension benefit obligation, other postretirement benefit obligations and related plan assets for NRG's plans on a combined basis is as follows:

			As of December 31,
			Pension Benefits												Other Postretirement Benefits
(In millions)			2024						2023						2024						2023
Benefit obligation at January 1			$	1,023					$	1,036					$	75					$	84
Service cost			3						5						—						—
Interest cost			48						50						3						4
Actuarial loss/(gain)			( 35 )						22						( 1 )						( 5 )
Employee and retiree contributions			—						—						3						4
Annuity purchase settlement			( 50 )						—						—						—
Curtailment and special termination benefit loss			—						( 2 )						—						( 1 )
Benefit payments			( 83 )						( 89 )						( 10 )						( 11 )
Foreign exchange translation			( 5 )						1						—						—
Benefit obligation at December 31			901						1,023						70						75
Fair value of plan assets at January 1			851						844						—						—
Actual return on plan assets			16						93						—						—
Employee and retiree contributions			—						—						3						4
Employer contributions			38						2						7						7
Annuity purchase settlement			( 50 )						—						—						—
Benefit payments			( 83 )						( 89 )						( 10 )						( 11 )
Foreign exchange translation			( 5 )						1						—						—
Fair value of plan assets at December 31			767						851						—						—
Funded status at December 31 — excess of obligation over assets			$	( 134 )					$	( 172 )					$	( 70 )					$	( 75 )

During the year ended December 31, 2024, the actuarial gain of $ 35 million on pension benefits was primarily driven by increasing discount rates.

During the year ended December 31, 2023, the actuarial loss of $ 22 million on pension benefits was primarily driven by decreasing discount rates.

Amounts recognized in NRG's balance sheets were as follows:

			As of December 31,
			Pension Benefits												Other Postretirement Benefits
(In millions)			2024						2023						2024						2023
Other current liabilities			$	—					$	—					$	5					$	5
Other non-current liabilities			134						172						65						70

Amounts recognized in NRG's accumulated OCI that have not yet been recognized as components of net periodic benefit cost were as follows:

			As of December 31,
			Pension Benefits												Other Postretirement Benefits
(In millions)			2024						2023						2024						2023
Net loss/(gain)			$	73					$	73					$	( 14 )					$	( 14 )
Prior service cost/(credit)			—						—						( 1 )						( 4 )
Total accumulated OCI			$	73					$	73					$	( 15 )					$	( 18 )

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Other changes in plan assets and benefit obligations recognized in OCI were as follows:

			Year Ended December 31,
			Pension Benefits												Other Postretirement Benefits
(In millions)			2024						2023						2024						2023
Net actuarial (gain)/loss			$	( 4 )					$	( 31 )					$	( 1 )					$	( 5 )
Amortization of net actuarial loss			( 2 )						( 6 )						1						( 1 )
Settlement (gain)/loss			6						—						—						—
Amortization of prior service cost			—						—						3						8
Effect of settlement/curtailment			—						( 1 )						—						( 1 )
Total recognized in OCI			$	—					$	( 38 )					$	3					$	1
Net periodic benefit cost/(credit)			—						21						( 1 )						( 3 )
Net recognized in net periodic pension (credit)/cost and OCI			$	—					$	( 17 )					$	2					$	( 2 )

The following table presents the balances of significant components of NRG's pension plan:

			As of December 31,
			Pension Benefits
(In millions)			2024						2023
Projected benefit obligation			$	901					$	1,023
Accumulated benefit obligation			895						1,015
Fair value of plan assets			767						851

NRG's market-related value of its plan assets is the fair value of the assets. The fair values of the Company's pension plan assets by asset category and their level within the fair value hierarchy are as follows:

			Fair Value Measurements as of December 31, 2024
(In millions)			Quoted Prices in Active Markets for Identical Assets (Level 1)						Significant Observable Inputs (Level 2)						Total
Common/collective trust investment — U.S. equity			$	—					$	142					$	142
Common/collective trust investment — non-U.S. equity			—						105						105
Common/collective trust investment — non-core assets			—						50						50
Common/collective trust investment — fixed income			—						199						199
Short-term investment fund			25						—						25
Subtotal fair value			$	25					$	496					$	521
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity															29
Common/collective trust investment — fixed income															177
Common/collective trust investment — non-core assets															12
Partnerships/joint ventures															28
Total fair value															$	767

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			Fair Value Measurements as of December 31, 2023
(In millions)			Quoted Prices in Active Markets for Identical Assets (Level 1)						Significant Observable Inputs (Level 2)						Total
Common/collective trust investment — U.S. equity			$	—					$	156					$	156
Common/collective trust investment — non-U.S. equity			—						58						58
Common/collective trust investment — non-core assets			—						81						81
Common/collective trust investment — fixed income			—						188						188
Short-term investment fund			19						—						19
Subtotal fair value			$	19					$	483					$	502
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity															32
Common/collective trust investment — fixed income															243
Common/collective trust investment — non-core assets															47
Partnerships/joint ventures															27
Total fair value															$	851

In accordance with ASC 820, the Company determines the level in the fair value hierarchy within which each fair value measurement in its entirety falls, based on the lowest level input that is significant to the fair value measurement in its entirety. The fair value of the common/collective trust investments is valued at fair value which is equal to the sum of the market value of all of the fund's underlying investments. Certain common/collective trust investments have readily determinable fair value as they publish daily net asset value, or NAV, per share and are categorized as Level 2. Certain other common/collective trust investments and partnerships/joint ventures use NAV per share, or its equivalent, as a practical expedient for valuation, and thus have been removed from the fair value hierarchy table.

The following table presents the significant assumptions used to calculate NRG's benefit obligations:

			As of December 31,
			Pension Benefits												Other Postretirement Benefits
Weighted-Average Assumptions			2024						2023						2024						2023
Discount rate			5.63		%				4.97		%				5.55		%				4.96		%
Interest crediting rate			5.38		%				5.67		%				4.54		%				4.66		%
Rate of compensation increase			3.00		%				3.06		%				—						—
Health care trend rate			—						—						8.3 % grading to 4.5 % in 2034						7.7 % grading to 4.5 % in 2033

The following table presents the significant assumptions used to calculate NRG's benefit expense:

			As of December 31,
			Pension Benefits																		Other Postretirement Benefits
Weighted-Average Assumptions			2024						2023						2022						2024						2023						2022
Discount rate			4.99		%				5.18		%				2.89 %/ 4.71 %/ 5.41 %						4.96		%				5.19		%				2.82		%
Interest crediting rate			5.67		%				5.21		%				3.07		%				4.66		%				4.00		%				1.94		%
Expected return on plan assets			6.65		%				5.55		%				4.99		%				—						—						—
Rate of compensation increase			3.00		%				3.06		%				3.06		%				—						—						—
Health care trend rate			—						—						—						7.4 % grading to 4.5 % in 2033						7.2 % grading to 4.5 % in 2028						6.9 % grading to 4.4 % in 2028

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NRG uses December 31 of each respective year as the measurement date for the Company's pension and other postretirement benefit plans. The Company sets the discount rate assumptions on an annual basis for each of NRG's defined benefit retirement plans as of December 31. The discount rate assumptions represent the current rate at which the associated liabilities could be effectively settled at December 31. The Company utilizes the Aon AA Above Median, or AA-AM, yield curve and the AON Canada yield curve to select the appropriate discount rate assumption for its retirement plans. The AA-AM yield curve is a hypothetical AA yield curve represented by a series of annualized individual spot discount rates from 6 months to 99 years. Under the AA-AM yield curve, each bond issue used to build this yield curve must be non-callable, and have an average rating of AA when averaging available Moody's Investor Services, Standard & Poor's and Fitch ratings. The AON Canada yield curve is based on high quality corporate bonds. Under the AON Canada yield curve, expected plan cash flows were discounted using the yield curve, and then a single rate is determined which produces an equivalent present value.

NRG employs a total return investment approach, whereby a mix of equities and fixed income investments are used to maximize the long-term return of plan assets for a prudent level of risk. Risk tolerance is established through careful consideration of plan liabilities, plan funded status, and corporate financial condition. The Investment Committee reviews the asset mix periodically and as the plan assets increase in future years, the Investment Committee may examine other asset classes such as real estate or private equity. NRG employs a building block approach to determining the long-term rate of return assumption for plan assets, with proper consideration given to diversification and rebalancing. Historical markets are studied and long-term historical relationships between equities and fixed income are preserved, consistent with the widely accepted capital market principle that assets with higher volatility generate a greater return over the long run. Current factors such as inflation and interest rates are evaluated before long-term capital market assumptions are determined. Peer data and historical returns are reviewed to check for reasonableness and appropriateness.

The target allocations of NRG's pension plan assets were as follows for the year ended December 31, 2024:

U.S. equity			20		%
Non-U.S. equity			13		%
Non-core assets			17		%
Fixed income			50		%

Plan assets are currently invested in a diversified blend of equity and fixed-income investments. Furthermore, equity investments are diversified across U.S., non-U.S., global, and emerging market equities, as well as among growth, value, small and large capitalization stocks.

Investment risk and performance are monitored on an ongoing basis through quarterly portfolio reviews of each asset fund class to a related performance benchmark, if applicable, and annual pension liability measurements. Performance benchmarks are composed of the following indices:

Asset Class						Index
U.S. equities						Dow Jones U.S. Total Stock Market Index
Non-U.S. equities						MSCI All Country World Index
Non-core assets (a)						Various (per underlying asset class)
Fixed income securities						Barclays Short, Intermediate and Long Credits/Barclays Strips 20+ Index and FTSE Canada Universe Bond Index

(a) Non-Core Assets are defined as diversifying asset classes approved by the Investment Committee that are intended to enhance returns and/or reduce volatility of the U.S. and non-U.S. equities. Asset classes considered Non-Core include, but may not be limited to: Emerging Market Equity, Emerging Market Debt, Non-US Developed Market Small Cap, High Yield Fixed Income, Real Estate, Bank Loans, Global Infrastructure and other Alternatives

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NRG's expected future benefit payments for each of the next five years, and in the aggregate for the five years thereafter, are as follows:

			Pension						Other Postretirement Benefit
(In millions)			Benefit Payments						Benefit Payments						Medicare Prescription Drug Reimbursements
2025			$	93					$	5					$	—
2026			77						5						—
2027			75						5						—
2028			73						5						—
2029			71						5						—
2030-2034			336						28						2

Defined Contribution Plans

NRG's employees are also eligible to participate in defined contribution 401(k) plans.

The Company's costs related to these plans were as follows:

			Year Ended December 31,
(In millions)			2024						2023						2022
Cost recognized for defined contribution plans			$	62					$	61					$	37

The Company's costs, which are primarily related to employer matching of a portion of employee contributions to defined contribution plans, increased during 2023 primarily due to an increase in retirement saving plan match and the Vivint acquisition.

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For the period from December 31, 2021 to December 31, 2024, the Company had 10,000,000 shares of preferred stock authorized and 500,000,000 shares of common stock authorized. The following table reflects the changes in NRG's preferred and common shares issued and outstanding for each period presented:

			Preferred Shares						Common Shares
			Issued and Outstanding						Issued						Treasury						Outstanding
Balance as of December 31, 2021			—						423,547,174						( 179,793,275 )						243,753,899
Shares issued under ESPP			—						—						142,825						142,825
Shares issued under LTIPs			—						349,827						—						349,827
Share repurchases			—						—						( 14,685,521 )						( 14,685,521 )
Balance as of December 31, 2022			—						423,897,001						( 194,335,971 )						229,561,030
Issuance of Series A Preferred Stock			650,000						—						—						—
Shares issued under ESPP			—						—						191,249						191,249
Shares issued under LTIPs			—						1,109,611						—						1,109,611
Share repurchases			—						—						( 22,730,940 )						( 22,730,940 )
Retirement of treasury stock			—						( 157,676,142 )						157,676,142						—
Balance as of December 31, 2023			650,000						267,330,470						( 59,199,520 )						208,130,950
Shares issued under ESPP			—						—						242,070						242,070
Shares issued under LTIPs			—						1,959,134						—						1,959,134
Share repurchases			—						—						( 11,725,563 )						( 11,725,563 )
Partial settlement of Capped Call Options			—						—						( 2,588 )						( 2,588 )
Retirement of treasury stock			—						( 64,225,546 )						64,225,546						—
Balance as of December 31, 2024			650,000						205,064,058						( 6,460,055 )						198,604,003
Shares issued under LTIPs			—						540,996						—						540,996
Share repurchases			—						—						( 1,076,423 )						( 1,076,423 )
Retirement of treasury stock			—						( 1,028,193 )						1,028,193						—
Balance as of January 31, 2025			650,000						204,576,861						( 6,508,285 )						198,068,576

Common Stock

As of December 31, 2024, NRG had 25,400,076 shares of common stock reserved for the maximum number of shares potentially issuable based on the conversion and redemption features of the long-term incentive plans.

Common Stock Dividends

The Company declared and paid $ 0.4075 , $ 0.3775 and $ 0.350 quarterly dividend per common share, or $ 1.63 , $ 1.51 and $ 1.40 per share on an annualized basis for 2024, 2023 and 2022 respectively.

In 2022, 2023 and 2024, NRG increased the annual dividend on its common stock to $ 1.40 , $ 1.51 and $ 1.63 per share, respectively, representing an 8 % increase each year. Beginning in the first quarter of 2025, NRG will increase the annual common stock dividend by 8 % to $ 1.76 per share. The long-term capital allocation policy targets an annual common stock dividend growth rate of 7 %- 9 % per share in subsequent years.

The Company's common stock dividends are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations.

On January 22, 2025, NRG declared a quarterly dividend on the Company's common stock of $ 0.44 per share, or $ 1.76 per share on an annualized basis, payable on February 18, 2025, to stockholders of record as of February 3, 2025.

Employee Stock Purchase Plan

The Company offers participation in the ESPP which allows eligible employees to elect to withhold between 1 % and 10 % of their eligible compensation to purchase shares of NRG common stock at the lesser of 90 % of its market value on the offering date or 90 % of the fair market value on the exercise date. An offering date occurs each April 1 and October 1. An exercise date occurs each September 30 and March 31. As of December 31, 2024, there remained 6,460,055 shares of treasury stock reserved for issuance under the ESPP.

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Share Repurchases

During the year ended December 31, 2022, the Company completed $ 595 million of share repurchases at an average price per share of $ 40.48 . In June 2023, NRG revised its long-term capital allocation policy to target allocating approximately 80 % of cash available for allocation, after debt reduction, to be returned to shareholders. As part of the revised capital allocation framework, the Company announced an increase to its share repurchase authorization to $ 2.7 billion, to be executed through 2025. In October 2024, the Board of Directors authorized an additional $ 1.0 billion for share repurchases as part of the existing share repurchase authorization. As of January 31, 2025, $ 1.5 billion is remaining under the $ 3.7 billion authorization. The following table summarizes the share repurchases made under the $ 3.7 billion authorization through January 31, 2025:

			Total number of shares purchased			Average price paid per share			Amounts paid for shares purchased (in millions)
2023 Repurchases:
Open market repurchases			5,054,798			$	39.56		$	200
Repurchases made under the accelerated share repurchase agreements			17,676,142			(a)			950
Total Share Repurchases during 2023			22,730,940						1,150			(b)
2024 Repurchases:
Repurchases made under the accelerated share repurchase agreements			1,163,230			(a)			—
Open market repurchases			10,562,333			87.57			925
Total Share Repurchases during 2024			11,725,563						925			(c)
Repurchases made subsequent to December 31, 2024 thru January 31, 2025			1,076,423			101.07			109
Total Share Repurchases made under the $ 3.7 billion authorization			35,532,926			$	61.46		$	2,184

(a) Under the November 6, 2023 ASR, the Company received a total of 18,839,375 shares for an average price per share of $ 50.43 , excluding the impact of the excise tax incurred. See discussion below for further information of the ASR agreements

(b) Excludes $ 10 million of excise tax accrued in 2023 which was paid in 2024

(c) Excludes $ 9 million accrued for estimated excise tax owed as of December 31, 2024

On November 6, 2023, the Company executed Accelerated Share Repurchase agreements to repurchase a total of $ 950 million of NRG's outstanding common stock based on volume-weighted average prices. The Company received 17,676,142 shares in the fourth quarter of 2023, which were recorded in treasury stock at fair value based on the volume-weighted average closing prices of $ 833 million, with the remaining $ 117 million recorded in additional paid in capital, representing the value of the forward contracts to purchase additional shares. During the first quarter of 2024, the Company received an additional 1,163,230 shares pursuant to the ASR agreements. Upon receipt of the final shares, the Company transferred the $ 117 million from additional paid-in-capital to treasury stock.

Retirement of Treasury Stock

During the years ended December 31, 2024 and 2023, the Company retired shares of treasury stock as detailed below. These retired shares are now included in NRG's pool of authorized but unissued shares. The Company's accounting policy upon the formal retirement of treasury stock is to deduct its par value from common stock and to reflect any excess of cost over par value as a deduction from additional paid-in capital.

			Total number of treasury shares retired						Average price per share						Carrying value of treasury shares retired (in millions)
Shares retired during the year ended December 31, 2023			157,676,142						$	31.77					$	5,009
Shares retired during the year ended December 31, 2024			64,225,546						$	41.07					$	2,638

Capped Call Options

During the second quarter of 2024, the Company entered into privately negotiated capped call transactions with certain counterparties (the "Capped Calls"). The Capped Calls each have a strike price of $ 40.94 per share, subject to certain adjustments, which correspond to the conversion price of the Convertible Senior Notes as of December 31, 2024. The Capped Calls have a cap price of $ 249.00 per share, subject to certain adjustments, and effectively lock in a conversion premium of $ 257 million on the remaining $ 232 million balance of the Convertible Senior Notes. The options will expire on June 1, 2025 if not exercised. The Capped Calls are separate transactions and not part of the terms of the Convertible Senior Notes. As these transactions meet certain accounting criteria, the Capped Calls are recorded in stockholders' equity. The option price of $ 257 million incurred in connection with the Capped Calls, of which $ 253 million was recorded as a reduction to additional paid-in capital and a $ 4 million loss was recorded to other income, net to account for the change in the value of the Capped

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Calls during the calculation period which began on May 31, 2024 and concluded on June 28, 2024. The option price will be payable upon the earlier of settlement and expiration of the applicable Capped Calls.

Preferred Stock

Series A Preferred Stock

On March 9, 2023 ("Series A Issuance Date"), the Company issued 650,000 shares of 10.25 % Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock. The net proceeds of $ 635 million, net of issuance costs, were used to partially fund the Vivint Smart Home acquisition.

The Series A Preferred Stock is not convertible into or exchangeable for any other securities or property and has limited voting rights. The Series A Preferred Stock may be redeemed, in whole or in part, on one or more occasions, at the option of the Company at any time after March 15, 2028 ("Series A First Reset Date") and in certain other circumstances prior to the Series A First Reset Date. The Series A Preferred Stock has a liquidation preference of $ 1,000 per share, plus accumulated but unpaid dividends.

Series A Preferred Stock Dividends

The annual dividend rate on each share of Series A Preferred Stock is 10.25 % from the Series A Issuance Date to, but excluding the Series A First Reset Date. On and after the Series A First Reset Date, the dividend rate on each share of Series A Preferred Stock shall equal the five-year U.S. Treasury rate as of the most recent reset dividend determination date (subject to a floor of 1.00 %), plus a spread of 5.92 % per annum. Cumulative cash dividends on the Series A Preferred Stock are payable semiannually, in arrears, on each March 15 and September 15, when, as and if declared by the Board of Directors.

In March and September 2024, the Company declared and paid semi-annual dividends of $ 51.25 per share on its outstanding Series A Preferred Stock, each totaling $ 33 million. In September 2023, the Company declared and paid a semi-annual dividend of $ 52.96 per share, totaling $ 34 million.

Entities that are not Consolidated

NRG accounts for the Company's significant investments using the equity method of accounting. NRG's carrying value of equity investments can be impacted by a number of elements including impairments and movements in foreign currency exchange rates.

The following table summarizes NRG's equity method investments as of December 31, 2024:

(In millions, except percentages)
Name:			Economic Interest						Investment Balance
Gladstone (a)			37.5		%				$	34
Midway-Sunset Cogeneration Company			50.0		%				11
Total equity investments in affiliates									$	45

(a) As of December 31, 2024, the carrying value of NRG's equity method investment was $ 39 million lower than the underlying net assets of the investee. The basis difference is being amortized into net income over the remaining estimated useful lives of the underlying net assets. For the year ended December 31, 2024, the Company recorded $ 7 million of impairment losses on Gladstone. Refer to Note 10, Asset Impairments

The following table summarizes the undistributed earnings from NRG's equity method investments as of December 31, 2024:

			As of December 31,
(In millions)			2024						2023
Undistributed earnings			$	5					$	—

Other Equity Investments

Gladstone — Through a joint venture, NRG owns a 37.5 % interest in Gladstone, a 1,613 MW coal-fueled power generation facility in Queensland, Australia. The power generation facility is managed by the joint venture participants and the facility is operated by NRG. Operating expenses incurred in connection with the operation of the facility are funded by each of the participants in proportion to their ownership interests. Coal is sourced from local mines in Queensland. NRG and the joint venture participants receive their respective share of revenues directly from the off takers in proportion to the ownership interests in the joint venture. Power generated by the facility is primarily sold to an adjacent aluminum smelter, with excess power sold to the Queensland Government-owned utility under long-term supply contracts. NRG's investment in Gladstone was $ 34 million as of December 31, 2024.

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Variable Interest Entities that are Consolidated

The Company has a controlling financial interest that has been identified as a VIE under ASC 810 in NRG Receivables LLC, which has entered into financing transactions related to the Receivables Facility as further described in Note 12, Long-term Debt and Finance Leases.

The summarized financial information for the Company's consolidated VIE consisted of the following:

(In millions)			December 31, 2024						December 31, 2023
Accounts receivable and Other current assets			$	2,402					$	1,541
Current liabilities			155						153
Net assets			$	2,247					$	1,388

Basic income/(loss) per common share is computed by dividing net income/(loss) less cumulative dividends attributable to preferred stock by the weighted average number of common shares outstanding. Shares issued and treasury shares repurchased during the year are weighted for the portion of the year that they were outstanding. Diluted income/(loss) per share is computed in a manner consistent with that of basic income/(loss) per share, while giving effect to all potentially dilutive common shares that were outstanding during the period when there is net income.

Dilutive effect for equity compensation and other equity instruments — The relative performance stock units and non-vested restricted stock units are not considered outstanding for purposes of computing basic income/(loss) per share. However, these instruments are included in the denominator for purposes of computing diluted income/(loss) per share under the treasury stock method for periods when there is net income. The Convertible Senior Notes are convertible, under certain circumstances, into cash or combination of cash and Company’s common stock. The Company is including the potential share settlements, if any, in the denominator for purposes of computing diluted income/(loss) per share under the if converted method for periods when there is net income. The potential shares settlements are calculated as the excess of the Company's conversion obligation over the aggregate principal amount (which will be settled in cash), divided by the average share price for the period.

The reconciliation of NRG's basic and diluted income/(loss) per share is shown in the following table:

			Year Ended December 31,
(In millions, except per share amounts)			2024						2023						2022
Basic income/(loss) per share:
Net income/(loss)			$	1,125					$	( 202 )					$	1,221
Less: Cumulative dividends attributable to Series A Preferred Stock			67						54						—
Income/(Loss) Available to Common Stockholders			$	1,058					$	( 256 )					$	1,221
Weighted average number of common shares outstanding - basic			206						228						236
Income/(Loss) per weighted average common share — basic			$	5.14					$	( 1.12 )					$	5.17
Diluted income/(loss) per share:
Net income/(loss)			$	1,125					$	( 202 )					$	1,221
Less: Cumulative dividends attributable to Series A Preferred Stock			67						54						—
Income/(Loss) Available to Common Stockholders			$	1,058					$	( 256 )					$	1,221
Weighted average number of common shares outstanding - basic			206						228						236
Incremental shares attributable to the issuance of equity compensation (treasury stock method)			3						—						—
Incremental shares attributable to the potential share settlement of Convertible Senior Notes (if converted method)			3						—						—
Weighted average number of common shares outstanding - diluted			212						228						236
Income/(Loss) per weighted average common share — diluted			$	4.99					$	( 1.12 )					$	5.17

As of December 31, 2024 and 2022, the Company had an insignificant number of outstanding equity instruments that were anti-dilutive and were not included in the computation of the Company’s diluted income per share. As of December 31, 2023, the Company had 6 million of outstanding equity instruments that were anti-dilutive and were not included in the computation of the Company’s diluted loss per share.

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The Company’s segment structure reflects how management makes financial decisions and allocates resources. The Company manages its operations based on the combined results of the retail, wholesale and generation businesses with a geographical focus except for Vivint Smart Home operations which are reported within the Vivint Smart Home segment. Corporate represents the corporate business activities, and corporate shared services, to support the Company’s operating segments. Beginning in the fourth quarter of 2024, Corporate now includes interest expense related to its consolidated debt financing activities and income tax expense related to its consolidated U.S. federal, foreign and state income taxes conforming to the way the Company internally manages and monitors the business. Prior periods amounts have been recast for comparative purposes to reflect this change, which had no impact on the Company’s consolidated financial position, results of operations, and cash flows. The accounting policies of the segments are the same as those applied in the consolidated financial statements as disclosed in Note 2, Summary of Significant Accounting Policies .

NRG's chief operating decision maker ("CODM"), its chief executive officer, uses more than one measure to evaluate the performance of its segments and allocate resources, including net income/(loss) and various non-GAAP financial measures such as adjusted earnings before interest, taxes, depreciation and amortization, or Adjusted EBITDA. Net income/(loss) and Adjusted EBITDA are used to review business performance and allocate resources as it provides a clearer view of segment profitability by focusing on operational performance. Additionally, operating expenses’ impact on each operating segment results are analyzed. On a monthly basis, Adjusted EBITDA is compared against the budget, latest forecast, and prior period.

The Company had no customer that comprised more than 10% of the Company's consolidated revenues during the years ended December 31, 2024, 2023 and 2022.

Intersegment sales are accounted for at market.

			For the Year Ended December 31, 2024
(In millions)			Texas						East						West/Services/Other						Vivint Smart Home						Corporate (a)						Eliminations						Total
Revenue (a)			$	10,653					$	11,707					$	3,886					$	1,932					$	—					$	( 48 )					$	28,130
Operating Expenses			9,785						9,746						3,874						1,037						81						( 48 )						24,475
Depreciation and amortization			323						158						114						767						41						—						1,403
Impairment losses			7						—						29						—						—						—						36
Total operating cost and expenses			10,115						9,904						4,017						1,804						122						( 48 )						25,914
(Loss)/gain on sale of assets			( 4 )						3						209						—						—						—						208
Operating income/(loss)			534						1,806						78						128						( 122 )						—						2,424
Equity in earnings of unconsolidated affiliates			—						—						20						—						—						—						20
Impairment losses on investments			—						—						( 7 )						—						—						—						( 7 )
Other income, net			—						( 1 )						6						( 15 )						54						—						44
Loss on debt extinguishment			—						—						—						—						( 382 )						—						( 382 )
Interest expense			—						—						—						—						( 651 )						—						( 651 )
Income/(loss) before income taxes			534						1,805						97						113						( 1,101 )						—						1,448
Income tax expense			—						—						—						—						323						—						323
Net income/(loss)			$	534					$	1,805					$	97					$	113					$	( 1,424 )					$	—					$	1,125
Balance sheet
Equity investments in affiliates			$	—					$	—					$	45					$	—					$	—					$	—					$	45
Capital expenditures			369						3						16						23						61						—						472
Goodwill			643						721						153						3,494						—						—						5,011
Total assets			$	6,925					$	8,021					$	2,254					$	6,624					$	15,543					$	( 15,345 )					$	24,022

(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues			$	22					$	—					$	18					$	8					$	—					$	—					$	48

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			For the Year Ended December 31, 2023
(In millions)			Texas						East						West/Services/Other						Vivint Smart Home (a)						Corporate (b)						Eliminations						Total
Revenue (b)			$	10,476					$	12,547					$	4,281					$	1,549					$	—					$	( 30 )					$	28,823
Operating Expenses			8,353						14,361						5,021						858						133						( 30 )						28,696
Depreciation and amortization			348						167						99						645						36						—						1,295
Impairment losses			2						4						20						—						—						—						26
Total operating cost and expenses			8,703						14,532						5,140						1,503						169						( 30 )						30,017
Gain on sale of assets			1,319						259						—						—						—						—						1,578
Operating income/(loss)			3,092						( 1,726 )						( 859 )						46						( 169 )						—						384
Equity in earnings of unconsolidated affiliates			—						—						16						—						—						—						16
Impairment losses on investments			—						—						( 102 )						—						—						—						( 102 )
Other income, net			2						( 1 )						1						( 15 )						60						—						47
Gain on debt extinguishment			—						—						—						—						109						—						109
Interest expense			—						—						—						—						( 667 )						—						( 667 )
Income/(loss) before income taxes			3,094						( 1,727 )						( 944 )						31						( 667 )						—						( 213 )
Income tax benefit			—						—						—						—						( 11 )						—						( 11 )
Net income/(loss)			$	3,094					$	( 1,727 )					$	( 944 )					$	31					$	( 656 )					$	—					$	( 202 )
Balance sheet
Equity investments in affiliates			$	—					$	—					$	42					$	—					$	—					$	—					$	42
Capital expenditures			495						5						27						18						53						—						598
Goodwill			643						721						221						3,494						—						—						5,079
Total assets (c)			$	8,236					$	13,712					$	3,612					$	6,619					$	20,357					$	( 26,498 )					$	26,038

(a) Includes results of operations following the acquisition date of March 10, 2023
(b) Inter-segment sales and inter-segment net derivative gains and losses included in revenues			$	5					$	9					$	16					$	—					$	—					$	—					$	30
(c) Tax related balances have been recast to Corporate for comparative purposes

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			For the Year Ended December 31, 2022
(In millions)			Texas						East						West/Services/Other						Corporate (a)						Eliminations						Total
Revenue (a)			$	10,057					$	16,763					$	4,706					$	—					$	17					$	31,543
Operating Expenses			8,444						15,998						4,106						86						17						28,651
Depreciation and amortization			361						241						87						31						—						720
Impairment losses			—						206						—						—						—						206
Total operating cost and expenses			8,805						16,445						4,193						117						17						29,577
Gain/(loss) on sale of assets			10						—						45						( 3 )						—						52
Operating income			1,262						318						558						( 120 )						—						2,018
Equity in (losses)/earnings of unconsolidated affiliates			( 2 )						—						8						—						—						6
Other income, net			4						1						1						50						—						56
Interest expense			—						—						—						( 417 )						—						( 417 )
Income/(loss) before income taxes			1,264						319						567						( 487 )						—						1,663
Income tax expense			—						—						—						442						—						442
Net income/(loss)			$	1,264					$	319					$	567					$	( 929 )					$	—					$	1,221

(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues			$	4					$	( 26 )					$	5					$	—					$	—					$	( 17 )

The income tax provision consisted of the following amounts:

			Year Ended December 31,
(In millions, except effective income tax rate)			2024						2023						2022
Current
U.S. Federal			$	55					$	26					$	3
State			82						84						65
Foreign			5						( 12 )						3
Total — current			142						98						71
Deferred
U.S. Federal			333						50						258
State			( 134 )						( 61 )						59
Foreign			( 18 )						( 98 )						54
Total — deferred			181						( 109 )						371
Total income tax expense/(benefit)			$	323					$	( 11 )					$	442
Effective income tax rate			22.3		%				5.2		%				26.6		%

The IRA enacted on August 16, 2022, introduced new provisions including a 15% corporate alternative minimum tax and a 1% excise tax on net share repurchases with both taxes effective beginning in fiscal year 2023 for NRG. On September 12, 2024, Treasury and the IRS released proposed regulations that provide guidance on the application of the CAMT. The proposed regulations allow the exclusion of unrealized mark-to-market gains and losses, related to qualified hedge transactions, from adjusted financial statement income. The Company will continue to evaluate the applicable corporation status and the impact of the CAMT based on the proposed guidance. As of December 31, 2024, NRG as an applicable corporation is subject to the CAMT, and has reflected the impact in its current and deferred taxes. There is no impact on the Company’s provision for income taxes from the CAMT as of December 31, 2024.

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The following represented the domestic and foreign components of income/(loss) before income taxes:

			Year Ended December 31,
(In millions)			2024						2023						2022
U.S.			$	1,485					$	261					$	1,436
Foreign			( 37 )						( 474 )						227
Total			$	1,448					$	( 213 )					$	1,663

Reconciliations of the U.S. federal statutory tax rate to NRG's effective tax rate were as follows:

			Year Ended December 31,
(In millions, except effective income tax rate)			2024						2023						2022
Income/(Loss) before income taxes			$	1,448					$	( 213 )					$	1,663
Tax at federal statutory tax rate			304						( 45 )						349
State taxes			92						( 22 )						69
Foreign rate differential			1						( 10 )						7
Changes in state valuation allowances			( 110 )						42						( 3 )
Nondeductible loss on Convertible Senior Notes repurchases			56						—						—
Permanent differences			23						31						17
Stock compensation			( 19 )						—						—
Recognition of uncertain tax benefits			1						12						8
Deferred impact of state tax rate changes			( 24 )						3						14
Foreign tax refunds			—						( 17 )						—
Return to provision adjustments			( 1 )						( 5 )						—
Carbon capture tax credits			—						—						( 19 )
Income tax expense/(benefit)			$	323					$	( 11 )					$	442
Effective income tax rate			22.3		%				5.2		%				26.6		%

For the year ended December 31, 2024, NRG's effective income tax rate was higher than the federal statutory tax rate of 21% primarily due to permanent differences and state tax expense partially offset by tax benefits from the revaluation of state deferred tax assets, and decrease of certain state valuation allowances.

For the year ended December 31, 2023, NRG's effective income tax rate was lower than the federal statutory tax rate of 21% primarily due to permanent differences and changes in state valuation allowances.

For the year ended December 31, 2022, NRG's effective income tax rate was higher than the federal statutory tax rate of 21% primarily due to state tax expense partially offset by the recognition of carbon capture tax credits.

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The temporary differences, which gave rise to the Company's deferred tax assets and liabilities consisted of the following:

			As of December 31,
(In millions)			2024						2023
Deferred tax assets:
U.S. Federal net operating loss carryforwards			$	1,477					$	1,762
State net operating loss carryforwards			341						367
Foreign net operating loss carryforwards			106						110
Deferred revenues			335						347
Difference between book and tax basis of property			322						353
Federal and state tax credit carryforwards			269						317
Deferred compensation, accrued vacation and other reserves			174						141
Interest disallowance carryforward per §163(j) of the Tax Act			77						132
Pension and other postretirement benefits			46						48
Allowance for credit losses			37						35
Equity compensation			30						24
Federal benefit on state uncertain tax positions			13						13
Inventory obsolescence			13						11
U.S. capital loss			1						1
Other			46						33
Total deferred tax assets			3,287						3,694
Deferred tax liabilities:
Intangibles amortization (excluding goodwill)			486						726
Derivatives			193						156
Capitalized contract costs			249						131
Equity method investments			88						93
Goodwill			56						40
Debt discount amortization			—						26
Emissions allowances			16						18
Total deferred tax liabilities			1,088						1,190
Total deferred tax assets less deferred tax liabilities			2,199						2,504
Valuation allowance			( 144 )						( 275 )
Total net deferred tax assets, net of valuation allowance			$	2,055					$	2,229

The following table summarizes NRG's net deferred tax position as presented in the consolidated balance sheets:

			As of December 31,
(In millions)			2024						2023
Deferred tax asset			$	2,067					$	2,251
Deferred tax liability			( 12 )						( 22 )
Net deferred tax asset			$	2,055					$	2,229

The primary drivers for the decrease in the net deferred tax asset from $ 2.2 billion as of December 31, 2023 to $ 2.1 billion as of December 31, 2024 is due to utilization of net operating losses, partially offset by the decrease of certain state valuation allowances.

Deferred tax assets and valuation allowance

Net deferred tax balance — As of December 31, 2024 and 2023, NRG recorded a net deferred tax asset, excluding valuation allowance, of $ 2.2 billion and $ 2.5 billion, respectively. The Company believes certain state net operating losses may not be realizable under the more-likely-than-not measurement and as such, a valuation allowance was recorded as of December 31, 2024 as discussed below.

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NOL carryforwards — As of December 31, 2024, the Company had tax-effected cumulative U.S. NOLs consisting of carryforwards for federal and state income tax purposes of $ 1.5 billion and $ 341 million, respectively. In addition, NRG has tax-effected cumulative foreign NOL carryforwards of $ 106 million. The majority of NRG's NOL carryforwards have no expiration date.

Valuation allowance — As of December 31, 2024, the Company's tax-effected valuation allowance was $ 144 million, consisting of state NOL carryforwards and foreign NOL carryforwards. The valuation allowance was recorded based on the assessment of cumulative and forecasted pre-tax book earnings and the future reversal of existing taxable temporary differences.

Taxes Receivable and Payable

As of December 31, 2024, NRG recorded a current federal payable of $ 1 million, a current net state receivable of $ 1 million and a current net foreign receivable of $ 8 million.

Uncertain tax benefits

NRG has identified uncertain tax benefits with after-tax value of $ 57 million and $ 73 million as of December 31, 2024 and 2023, for which NRG has recorded a non-current tax liability of $ 62 million and $ 76 million, respectively. The Company recognizes interest and penalties related to uncertain tax benefits in income tax expense. The Company recognized $ 2 million of interest expense for the year ended December 31, 2024, and $ 1 million for the years ended December 31, 2023 and 2022. As of December 31, 2024 and 2023, NRG had cumulative interest and penalties related to these uncertain tax benefits of $ 5 million and $ 3 million, respectively.

Tax jurisdictions — NRG is subject to examination by taxing authorities for income tax returns filed in the U.S. federal jurisdiction and various state and foreign jurisdictions including operations located in Australia and Canada.

The Company is no longer subject to U.S. federal income tax examinations for years prior to 2021. With few exceptions, state and Canadian income tax examinations are no longer open for years before 2015.

The following table summarizes uncertain tax benefits activity:

			As of December 31,
(In millions)			2024						2023
Balance as of January 1			$	73					$	22
Increase due to current year positions			12						28
Increase due to acquired balance from Vivint Smart Home			—						23
Settlements, payments and statute closure			( 28 )						—
Uncertain tax benefits as of December 31			$	57					$	73

The Company's stock-based compensation consists of awards granted under the NRG LTIP and following the Acquisition in March 2023, the Vivint LTIP.

NRG Energy, Inc. Long-Term Incentive Plan

As of December 31, 2024 and 2023, a total of 25,000,000 shares of NRG common stock were authorized for issuance under the NRG LTIP. There were 7,188,824 and 7,717,139 shares of common stock remaining available for grants under the NRG LTIP as of December 31, 2024 and 2023, respectively. The NRG LTIP is subject to adjustments in the event of reorganization, recapitalization, stock split, reverse stock split, stock dividend, and a combination of shares, merger or similar change in NRG's structure or outstanding shares of common stock. As of December 31, 2024, the outstanding awards under the NRG LTIP include restricted stock units, deferred stock units and relative performance stock units.

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Restricted Stock Units

As of December 31, 2024, RSUs granted under the NRG LTIP typically have three -year graded vesting schedules beginning on the grant date. Fair value of the RSUs granted during 2024 and 2023 is derived from the closing price of NRG common stock on the grant date. The following table summarizes the Company's non-vested RSU awards and changes during the year:

			Units						Weighted Average Grant Date Fair Value per Unit
Non-vested at December 31, 2023			1,210,840						$	37.88
Granted			413,872						51.89
Forfeited			( 49,082 )						39.43
Vested			( 525,470 )						38.38
Non-vested at December 31, 2024			1,050,160						42.95

The total fair value of RSUs vested during the years ended December 31, 2024, 2023 and 2022 was $ 47 million, $ 20 million and $ 10 million, respectively. The weighted average grant date fair value of RSUs granted during the years ended December 31, 2024, 2023 and 2022 was $ 51.89 , $ 35.71 and $ 41.26 , respectively.

Deferred Stock Units

DSUs represent the right of a participant to be paid one share of NRG common stock at the end of a deferral period established under the terms of the award. DSUs granted under the NRG LTIP are fully vested at the date of issuance. Fair value of the DSUs, which is based on the closing price of NRG common stock on the date of grant, is recorded as compensation expense in the period of grant.

The following table summarizes the Company's outstanding DSU awards and changes during the year:

			Units						Weighted Average Grant Date Fair Value per Unit
Outstanding at December 31, 2023			443,287						$	29.07
Granted			46,617						76.31
Converted to Common Stock			( 112,784 )						30.73
Outstanding at December 31, 2024			377,120						33.91

The aggregate intrinsic values for DSUs outstanding as of December 31, 2024, 2023 and 2022 were approximately $ 34 million, $ 23 million and $ 13 million, respectively. The aggregate intrinsic values for DSUs converted to common stock for the years ended December 31, 2024, 2023 and 2022 were $ 10 million, $ 3 million and $ 1 million, respectively. The weighted average grant date fair value of DSUs granted during the years ended December 31, 2024, 2023 and 2022 was $ 76.31 , $ 34.40 and $ 45.49 , respectively.

Relative Performance Stock Units

RPSUs entitle the recipient to stock upon vesting. The amount of the award is subject to the Company's achievement of certain performance measures over the vesting period. RPSUs are restricted grants where the quantity of shares increases and decreases alongside the Company's Total Shareholder Return ("TSR"), relative to the TSR of the Company's current proxy peer group and the total returns of select indexes, or Peer Group. The peer group consists of the companies that comprise the Standard & Poor’s 500 Index on the first day of the performance period. Each RPSU represents the potential to receive NRG common stock after the completion of the performance period, typically three years of service from the date of grant. The number of shares of NRG common stock to be paid (if any) as of the vesting date for each RPSU will depend on the Company’s percentile rank within the Peer Group. The number of shares of common stock to be paid as of the vesting date for each RPSU is linearly interpolated for TSR performance between the following points: (i) 0 % if ranked below the 25th percentile; (ii) 25 % if ranked at the 25th percentile; (iii) 100 % if ranked at the 55th percentile (or the 65th percentile if the Company's absolute TSR is less than negative 15 %); and (iv) 200 % if ranked at the 75th percentile or above.

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The following table summarizes the Company's non-vested RPSU awards and changes during the year:

			Units						Weighted Average Grant-Date Fair Value per Unit
Non-vested at December 31, 2023			671,889						$	46.27
Granted			380,370						62.48
Forfeited			( 22,623 )						52.55
Vested			( 316,685 )						49.50
Non-vested at December 31, 2024			712,951						53.10

The weighted average grant date fair value of RPSUs granted during the years ended December 31, 2024, 2023 and 2022, was $ 62.48 , $ 39.46 and $ 57.41 , respectively.

The fair value of RPSUs is estimated on the date of grant using a Monte Carlo simulation model and expensed over the service period, which equals the vesting period. Significant assumptions used in the fair value model with respect to the Company's RPSUs are summarized below:

			2024						2023						2022
Expected volatility			34.46		%				41.35		%				37.54		%
Expected term (in years)			3						3						3
Risk free rate			4.05		%				4.18		%				0.97		%

The expected volatility is calculated based on NRG's historical stock price volatility data over the period commensurate with the expected term of the RPSU, which equals the vesting period.

NRG Energy, Inc. 2020 Omnibus Incentive Plan (Legacy Vivint)

Effective March 10, 2023, in connection with the Vivint Smart Home Acquisition, as discussed in Note 4, Acquisitions and Dispositions, NRG assumed the NRG Energy, Inc. 2020 Omnibus Incentive Plan (Legacy Vivint) (formerly known as Vivint Smart Home, Inc. Long-Term Incentive Plan) or Vivint LTIP. In addition to the rollover awards converted as part of the Acquisition, the Vivint LTIP provides for issuances of time-based restricted stock units and performance-based restricted stock units. As of December 31, 2024 and 2023, 17,500,000 shares of NRG common stock were authorized for issuance under the Vivint LTIP. There were 12,557,143 and 12,749,736 shares of common stock remaining available for grants under the Vivint LTIP as of December 31, 2024 and 2023, respectively.

Restricted Stock Units

As of December 31, 2024, RSUs under the Vivint LTIP include RSUs which were granted prior to the Acquisition and were converted into awards that vest as NRG common stock ("Rollover RSUs"). These awards typically had four-year graded vesting schedules beginning on the grant date. The fair value of the Rollover RSUs is based on the fair value of NRG common stock on the Acquisition date after applying the conversion ratio as per the Merger Agreement. The RSUs that were granted following the Acquisition date are typically subject to the same terms as the RSUs under the NRG LTIP.

The following table summarizes the non-vested RSUs under the Vivint LTIP and changes during the year:

			Rollover RSUs												RSUs granted following the Acquisition
			Units						Weighted Average Grant Date Fair Value per Unit						Units						Weighted Average Grant Date Fair Value per Unit
Non-vested at December 31, 2023			2,984,901						$	31.63					780,298						$	35.24
Granted following the Acquisition date			—						—						800,032						56.02
Forfeited			( 194,314 )						31.63						( 82,973 )						41.38
Vested			( 1,440,844 )						31.63						( 318,774 )						39.52
Non-vested at December 31, 2024			1,349,743						31.63						1,178,583						47.19

The total fair value of RSUs vested during the years ended December 31, 2024 and 2023 was $ 159 million and $ 66 million, respectively. The weighted average grant date fair value of RSUs granted during the years ended December 31, 2024 and 2023 was $ 56.02 and $ 35.24 , respectively.

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Relative Performance Stock Units

As of December 31, 2024 and 2023, RPSUs granted under the Vivint LTIP are generally granted under the same terms as the RPSUs granted under the NRG LTIP, and are valued using the same methods and assumptions. The following table summarizes the Company's non-vested RPSUs under the Vivint LTIP and changes during the year:

			Units						Weighted Average Grant Date Fair Value per Unit
Non-vested at December 31, 2023			102,837						$	44.96
Granted			71,568						66.44
Forfeited			—						—
Vested			—						—
Non-vested at December 31, 2024			174,405						53.63

There were no RPSUs vested during the year ended December 31, 2024 and 2023. The weighted average grant date fair value of RPSUs granted during the years ended December 31, 2024 and 2023 was $ 66.44 and $ 44.96 , respectively.

Supplemental Information

The following table summarizes NRG's total compensation expense recognized for the years presented, as well as total non-vested compensation costs not yet recognized and the period over which this expense is expected to be recognized as of December 31, 2024, for each of the types of awards issued under the LTIPs. Minimum tax withholdings of $ 50 million, $ 22 million, and $ 6 million for the years ended December 31, 2024, 2023, and 2022, respectively, are reflected as a reduction to additional paid-in capital on the Company's consolidated balance sheets.

																					Non-vested Compensation Cost
(In millions, except weighted average data)			Compensation Expense																		Unrecognized Total Cost						Weighted Average Recognition Period Remaining (In years)
			Year Ended December 31,																		As of December 31,
Award			2024						2023						2022						2024						2024
RSUs under NRG LTIP			$	29					$	20					$	15					$	17					1.52
RSUs under Vivint LTIP			56						76						—						48						1.32
DSUs			3						2						2						—						0.00
RPSUs under NRG LTIP			11						3						11						15						1.17
RPSUs under Vivint LTIP			3						2						—						5						1.55
PRSUs (a)			43						20						6						68						1.33
Total			$	145					$	123					$	34					$	153
Tax (benefit)/detriment recognized			$	( 14 )					$	2					$	3

NRG provides services to some of its related parties, who are accounted for as equity method investments, under operations and maintenance agreements. Fees for the services under these agreements include recovery of NRG's costs of operating the plants. Certain agreements also include fees for administrative service, a base monthly fee, profit margin and/or annual incentive bonus.

The following table summarizes NRG's material related party transactions with third-party affiliates:

			Year Ended December 31,
(In millions)			2024						2023						2022
Revenues from Related Parties Included in Revenues
Gladstone			$	4					$	4					$	4
Ivanpah (a)			60						78						42
Midway-Sunset			4						2						6
Total			$	68					$	84					$	52

(a) Includes fees under project management agreements with each project company

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Commitments

NRG has entered into long-term contractual arrangements related to energy products, including power purchases, gas transportation and storage, fuel and transportation services and generation projects. These contracts are not included in the consolidated balance sheet as of December 31, 2024.

As of December 31, 2024, the Company's minimum commitments under such outstanding agreements are estimated as follows:

Period			(In millions)
2025			$	2,414
2026			2,422
2027			1,392
2028			941
2029			624
Thereafter			1,190
Total (a)			$	8,983

(a) The year 2025 does not include an additional $ 1.5 billion of short-term commitments. Increase from 2023 is primarily due to NPNS election for certain existing derivative contracts. For further discussion, see Note 6, Accounting for Derivative Instruments and Hedging Activities

The Company's actual costs may be significantly higher than these estimated minimum unconditional long-term firm commitments with remaining term in excess of one year. For the years ended December 31, 2024, 2023 and 2022, the costs of fuel and purchased energy were $ 12.2 billion, $ 13.4 billion and $ 19.6 billion, respectively.

First Lien Structure

NRG has granted first liens to certain counterparties on a substantial portion of property and assets owned by NRG and the guarantors of its senior debt. NRG uses the first lien structure to reduce the amount of cash collateral and letters of credit that it would otherwise be required to post from time to time to support its obligations under out-of-the-money hedges. To the extent that the underlying hedge positions for a counterparty are out-of-the-money to NRG, the counterparty would have a claim under the first lien program. As of December 31, 2024, all hedges under the first liens were in-the-money on a counterparty aggregate basis.

Contingencies

The Company's material legal proceedings are described below. The Company believes that it has valid defenses to these legal proceedings and intends to defend them vigorously. NRG records accruals for estimated losses from contingencies when information available indicates that a loss is probable and the amount of the loss, or range of loss, can be reasonably estimated. As applicable, the Company has established an adequate accrual for the applicable legal matters, including regulatory and environmental matters as further discussed in Note 23, Regulatory Matters , and Note 24, Environmental Matters . In addition, legal costs are expensed as incurred. Management has assessed each of the following matters based on current information and made a judgment concerning its potential outcome, considering the nature of the claim, the amount and nature of damages sought, and the probability of success. Unless specified below, the Company is unable to predict the outcome of these legal proceedings or reasonably estimate the scope or amount of any associated costs and potential liabilities. As additional information becomes available, management adjusts its assessment and estimates of such contingencies accordingly. Because litigation is subject to inherent uncertainties and unfavorable rulings or developments, it is possible that the ultimate resolution of the Company's liabilities and contingencies could be at amounts that are different from its currently recorded accruals and that such difference could be material.

In addition to the legal proceedings noted below, NRG and its subsidiaries are party to other litigation or legal proceedings arising in the ordinary course of business. In management's opinion, the disposition of these ordinary course matters will not materially adversely affect NRG's consolidated financial position, results of operations, or cash flows.

Environmental Lawsuits

Sierra club et al. v. Midwest Generation LLC — In 2012, several environmental groups filed a complaint against Midwest Generation with the Illinois Pollution Control Board ("IPCB") alleging violations of environmental law resulting in groundwater contamination. In June 2019, the IPCB found in an interim order that Midwest Generation violated the law because it had improperly handled coal ash at four facilities in Illinois and caused or allowed coal ash constituents to impact groundwater. On September 9, 2019, Midwest Generation filed a Motion to Reconsider numerous issues, which the court

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granted in part and denied in part on February 6, 2020. In 2023, the IPCB held hearings regarding the appropriate relief. Midwest Generation has been working with the Illinois EPA to address the groundwater issues since 2010.

Consumer Lawsuits

Similar to other energy service companies ("ESCOs") operating in the industry, from time-to-time, the Company and/or its subsidiaries may be subject to consumer lawsuits in various jurisdictions where they sell natural gas and electricity.

Variable Price Case

Mirkin v. XOOM Energy (E.D.N.Y. Aug. 2019) — XOOM Energy is a defendant in a putative class action lawsuit pending in New York, alleging that XOOM Energy promised that consumers would pay the same or less than they would have paid if they stayed with their default utility or previous energy supplier. The Court denied XOOM's motion for summary judgment and granted class certification. The Second Circuit denied XOOM's request to appeal the class certification grants. XOOM prevailed in its challenge to Mirkin's expert reports. The Court granted XOOM's motion to exclude both reports on damages. As a result, Mirkin has no method to establish damages for its class. The Court asked for further briefing on whether class certification can stand in light of the recent ruling. This matter was known and accrued for at the time of the XOOM acquisition.

Telephone Consumer Protection Act ("TCPA") Cases — In the cases set forth below, referred to as the TCPA Cases, such actions involve consumers alleging violations of the Telephone Consumer Protection Act of 1991, as amended, by receiving calls, texts or voicemails without consent in violation of the federal Telemarketing Sales Rule, and/or state counterpart legislation. The underlying claims of each case are similar. The Company denies the allegations asserted by plaintiffs and intends to vigorously defend these matters. These matters were known and accrued for at the time of the Direct Energy acquisition.

There are two putative class actions pending against Direct Energy: (1) Holly Newman v. Direct Energy, LP (D. Md Sept 2021) - Direct Energy filed its Motion to Dismiss asserting the ruling in the Brittany Burk v. Direct Energy (S.D. Tex. Feb 2019) preempts the Plaintiff's ability to file suit based on the same facts. The Court denied Direct Energy's motion stating the Court does not have the benefit of all of the facts that were in front of the Burk court to issue a similar ruling. On April 12, 2023, the Court granted Direct Energy’s Motion to Transfer Venue, moving to the case to the Southern District of Texas. The parties are proceeding with written discovery; and (2) Matthew Dickson v. Direct Energy (N.D. Ohio Jan. 2018) - The case was stayed pending the outcome of an appeal to the Sixth Circuit based on the unconstitutionality of the TCPA during the period from 2015-2020. The Sixth Circuit found the TCPA was in effect during that period and remanded the case back to the trial court. Direct Energy refiled its motions along with supplements. On March 25, 2022, the Court granted summary judgment in favor of Direct Energy and dismissed the case. Dickson appealed. The Sixth Circuit found that Dickson has standing and reversed the trial court's dismissal of the case. The matter is back at the trial court. The parties conducted fact and expert discovery and Direct Energy submitted its motion for summary judgment in August 2024.

Sales Practice Lawsuit

A Vivint Smart Home competitor has made a claim against Vivint Smart Home alleging, among other things, that Vivint Smart Home's sales representatives used deceptive sales practices. This matter was known and accrued for at the time of the Vivint Smart Home acquisition. CPI Security Systems, Inc. ("CPI") v. Vivint Smart Home, Inc. (W.D.N.C. Sept. 2020) was filed in 2020, went to trial, and in February 2023, the jury issued a verdict against Vivint Smart Home, in favor of CPI for $ 50 million of compensatory damages and an additional $ 140 million of punitive damages. Vivint Smart Home has fully briefed the appeal and oral argument was conducted on January 28, 2025. While Vivint Smart Home believes the CPI jury verdict is not legally or factually supported and awaits the issuance of the appellate court’s opinion, there can be no assurance that such defense efforts will be successful. This matter was adequately accrued for as of December 31, 2024.

SB IP Holdings LLC (“Skybell”) v. Vivint Smart Home, Inc. — O n October 23, 2023, a jury in the U.S. District Court, Eastern District of Texas, Sherman Division, issued a verdict against the Company in favor of Skybell for $ 45 million in damages for patent infringement. The patents that were the basis for the claims made by Skybell were ruled invalid by the U.S. International Trade Commission in November 2021. The Company does not believe the verdict is legally supported and is pursuing appellate remedies along with any other legal options available. At the time of the Vivint Smart Home acquisition, this matter was known and accrued for at the amount that was determined to be probable and reasonably estimable.

Contract Dispute

STP — In July 2023, the partners in STP, CPS and Austin Energy, initiated a lawsuit and filed to intervene in the license transfer application with the NRC, claiming a right of first refusal exists in relation to the proposed sale of NRG South Texas' 44% interest in STP to Constellation. The parties entered into a settlement agreement in May 2024, and the litigation was dismissed. There was no incremental impact to NRG as a result of the settlement.

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Winter Storm Uri Lawsuits

The Company has been named in certain property damage and wrongful death claims that have been filed in connection with Winter Storm Uri in its capacity as a generator and a REP. Most of the lawsuits related to Winter Storm Uri are consolidated into a single multi-district litigation matter in Harris County District Court. NRG's REPs have since been dismissed from the multi-district litigation. As a power generator, the Company is named in various cases with claims ranging from: wrongful death; personal injury only; property damage and personal injury; property damage only; and subrogation. The First Court of Appeals conditionally granted the generators' mandamus relief, ordering the trial court to grant the generator defendants' Motion to Dismiss. The plaintiffs challenged the ruling and the matters are stayed pending appeals by the various parties. The Company intends to vigorously defend these matters.

Environmental regulatory matters are discussed within Note 24, Environmental Matters .

NRG operates in a highly regulated industry and is subject to regulation by various federal, state and provincial agencies. As such, NRG is affected by regulatory developments at the federal, state and provincial levels and in the regions in which NRG operates. In addition, NRG is subject to the market rules, procedures, and protocols of the various ISO and RTO markets in which NRG participates. These power markets are subject to ongoing legislative and regulatory changes that may impact NRG's wholesale and retail operations.

In addition to the regulatory proceedings noted below, NRG and its subsidiaries are parties to other regulatory proceedings arising in the ordinary course of business or have other regulatory exposure. In management's opinion, the disposition of these ordinary course matters will not materially adversely affect NRG's consolidated financial position, results of operations, or cash flows.

California Station Power — As the result of unfavorable final and non-appealable litigation, the Company accrued a liability associated with consumption of station power at the Company's Encina power plant facility in California after August 30, 2010. The Company has established an appropriate accrual pending potential regulatory action by San Diego Gas & Electric regarding the Company's Encina facility.

Federal Trade Commission Investigation — In 2019, Vivint Smart Home received a civil investigative demand from the staff of the Federal Trade Commission (“FTC”) concerning potential violations of the Fair Credit Reporting Act and the “Red Flags Rule” thereunder, and the FTC Act. In April 2021, Vivint Smart Home entered into a settlement with the FTC that resolved this investigation. As part of this settlement, Vivint Smart Home paid $ 20 million and agreed to implement various additional compliance related measures ("Stipulated Order"). The Company is engaged in ongoing discussions with the staff of the FTC regarding the Company’s compliance with the terms of the Stipulated Order. Under the terms of the Stipulated Order, Vivint Smart Home is required to undertake biennial assessments by an independent third-party assessor (the "Assessor"), which reviews Vivint Smart Home’s compliance program and provides a report on Vivint Smart Home’s ongoing compliance with the Stipulated Order. Since its inception until December 31, 2023, Vivint Smart Home has completed its initial assessment and its first biennial assessment as required by the Stipulated Order. In addition, Vivint Smart Home has voluntarily undertaken nine quarterly audits by the appointed Assessor. In all the assessments, Vivint Smart Home received a report from the Assessor with no findings of non-compliance of any kind.

New York State Public Service Commission ("NYSPSC") - Notice of Apparent Violation — The NYSPSC issued an order referred to as the Retail Reset Order in December 2019 that limited ESCO's offers for electric and natural gas to three compliant products: guaranteed savings from the utility default rate, a fixed rate commodity product that is priced at no more than 5% greater than the trailing 12-month average utility supply rate or New York-sourced renewable energy that is at least 50% greater than the prevailing New York Renewable Energy Standard for load serving entities. The order effectively limited ESCO offers to natural gas customers to only the guaranteed savings and capped fixed term compliant products because no equivalent renewable energy product exists for natural gas. NRG took action to comply with the order when it became effective April 16, 2021. On January 8, 2024, the NYSPSC notified eight of NRG's retail energy suppliers (serving both electricity and natural gas) of alleged non-compliance with New York regulatory requirements. Among other items, the notices allege that the NRG suppliers did not transition existing residential customers to one of the three compliant products authorized by the NYSPSC following the effective date of the order. NRG responded to the notices in February 2024. The Company believes it has complied with the Retail Reset Order and does not agree with the NYSPSC's assertions made in the notice. The outcome of this process has the potential to negatively impact the retail business in New York.

NRG is subject to a wide range of environmental laws in the development, construction, ownership and operation of power plants. These laws generally require that governmental permits and approvals be obtained before construction and maintained during operation of power plants. The electric generation industry has been facing increasingly stringent

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requirements regarding air quality, GHG emissions, combustion byproducts, water use and discharge, and threatened and endangered species including four rules promulgated during the second quarter of 2024. In general, future laws are expected to require the addition of emissions controls or other environmental controls or to impose additional restrictions on the operations of the Company's facilities, which could have a material effect on the Company's consolidated financial position, results of operations, or cash flows. The Company has elected to use a $ 1 million disclosure threshold, as permitted, for environmental proceedings to which the government is a party.

Air

CPP/ACE Rules — The attention in recent years on GHG emissions has resulted in federal and state regulations. In 2019, the EPA promulgated the ACE rule, which rescinded the CPP, which had sought to broadly regulate CO 2 emissions from the power sector. The ACE rule required states that have coal-fired EGUs to develop plans to seek heat rate improvements from coal-fired EGUs. On January 19, 2021, the D.C. Circuit vacated the ACE rule (but on February 22, 2021, at the EPA's request, stayed the issuance of the portion of the mandate that would vacate the repeal of the CPP). On June 30, 2022, the U.S. Supreme Court held that the "generation shifting" approach in the CPP exceeded the powers granted to the EPA by Congress. The Court did not address the related issues of whether the EPA may adopt only measures applied at each source. On May 9, 2024, the EPA promulgated a rule that repealed the ACE rule and significantly revised the manner in which new combustion-turbine and existing steam EGU's GHG emissions will be regulated including capturing and storing/sequestering CO 2 in some instances. This rule has been challenged by numerous parties in the D.C. Circuit including 27 states with 22 states intervening in support of the rule. The DC Circuit held oral arguments related to this rule in December 2024. On February 5, 2025, the DOJ filed a motion asking the court to hold proceedings in abeyance while the new administration evaluates the rule. The court granted the motion on February 19, 2025.

CSAPR — On March 15, 2023, the EPA signed and released a prepublication version of a final rule that sought to significantly revise the CSAPR to address the good-neighbor obligations of the 2015 ozone NAAQS for 23 states after earlier having disapproved numerous state plans to address the issue. Several states, including Texas, challenged the EPA's disapproval of their state plans. On May 1, 2023, the U.S. Court of Appeals for the Fifth Circuit stayed the EPA's disapproval of Texas' and Louisiana's state plans, which disapprovals are a condition precedent to the EPA imposing its plan on Texas and Louisiana. Several other states are also similarly situated because of similar stays. Nonetheless, on June 5, 2023, the EPA promulgated this rule. On July 31, 2023, the EPA promulgated an interim final rule that addresses the various judicial orders that have stayed several State-Implementation-Plan disapprovals by limiting the effectiveness of certain requirements of the final rule promulgated on June 5, 2023 in Texas and several other states. On June 27, 2024, the U.S. Supreme Court stayed the final rule in the 11 states where the rule had not already been stayed. The Company cannot predict the outcome of the legal challenges to the: (i) various state disapprovals; (ii) the final rule promulgated on June 5, 2023; and (iii) the interim final rule promulgated on July 31, 2023 that seeks to address the judicial orders. The Company anticipates that the new U.S. presidential administration will revisit this rule.

Regional Haze Proposal — In May 2023, the EPA proposed to withdraw the existing Texas Sulfur Dioxide Trading Program and replace it with unit-specific SO 2 limits for 12 units in Texas to address requirements to improve visibility at National Parks and Wilderness areas. If finalized as proposed, it would result in more stringent SO 2 limits for two of the Company's coal-fired units in Texas. The Company cannot predict the outcome of this proposal.

Mercury and Air Toxics Standards (“MATS”) — On May 7, 2024, the EPA promulgated a final rule that amends the MATS rule by, among other things, increasing the stringency of the filterable particulate matter standard at coal-burning units. The deadline for complying with this more stringent standard is 2027. Twenty-three states have challenged this rule in the D.C. Circuit. Accordingly, the outcome of this rulemaking is uncertain. The Company anticipates that the new U.S. presidential administration will revisit this rule.

Water

ELG — In 2015, the EPA revised the ELG for Steam Electric Generating Facilities, which imposed more stringent requirements (as individual permits were renewed) for wastewater streams from FGD, fly ash, bottom ash and flue gas mercury control. On September 18, 2017, the EPA promulgated a final rule that, among other things, postponed the compliance dates to preserve the status quo for FGD wastewater and bottom ash transport water by two years to November 2020 until the EPA amended the rule. On October 13, 2020, the EPA amended the 2015 ELG rule by: (i) altering the stringency of certain limits for FGD wastewater; (ii) relaxing the zero-discharge requirement for bottom ash transport water; and (iii) changing several deadlines. In 2021, NRG informed its regulators that the Company intends to comply with the ELG by ceasing combustion of coal by the end of 2028 at its domestic coal units outside of Texas, and installing appropriate controls by the end of 2025 at its two plants that have coal-fired units in Texas. On May 9, 2024, the EPA promulgated a rule that revises the ELG by, among other things, further restricting the discharge of (i) FGD wastewater, (ii) bottom ash transport water, and (iii) combustion residual leachate. The rule was challenged in numerous courts, but the cases have been consolidated in the Eighth Circuit of the U.S. Court of Appeals. The outcome of the legal challenges is uncertain. On February 19, 2025, the DOJ filed a motion asking

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the court to hold proceedings in abeyance while the new administration evaluates the rule. The Company anticipates that the new U.S. presidential administration will revisit this rule.

Byproducts

In 2015, the EPA finalized the rule regulating byproducts of coal combustion (e.g., ash and gypsum) as solid wastes under the RCRA. On August 21, 2018, the D.C. Circuit found, among other things, that the EPA had not adequately regulated unlined ponds and legacy surface impoundments. On August 28, 2020, the EPA finalized "A Holistic Approach to Close Part A: Deadline to Initiate Closure," which amended the April 2015 Rule to address the August 2018 D.C. Circuit decision and extend some of the deadlines. On November 12, 2020, the EPA finalized "A Holistic Approach to Closure Part B: Alternative Demonstration for Unlined Surface Impoundments," which further amended the April 2015 Rule to, among other things, provide procedures for requesting approval to operate existing ash impoundments with an alternate liner. On May 8, 2024, the EPA promulgated a rule that establishes requirements for: (i) inactive (or legacy) surface impoundments at inactive facilities and (ii) CCR management units (regardless of how or when the CCR was placed) at regulated facilities. The rule also creates an obligation to conduct site assessments (at all active and certain inactive facilities) to determine whether CCR management units are present. The rule has been challenged in the D.C. Circuit and the outcome of the legal challenges is uncertain. The Company anticipates that the new U.S. presidential administration will revisit this rule.

Detail of supplemental disclosures of cash flow and non-cash investing and financing information was:

			Year Ended December 31,
(In millions)			2024						2023						2022
Interest paid, net of amount capitalized			$	626					$	548					$	383
Income taxes paid, net of refunds			182						48						66
Non-cash investing and financing activities:
Decreases to fixed assets for accrued capital expenditures			( 76 )						—						( 68 )
Excise tax accrued on share repurchases			9						10						—

NRG and its subsidiaries enter into various contracts that include indemnification and guarantee provisions as a routine part of the Company's business activities. Examples of these contracts include asset purchases and sale agreements, commodity sale and purchase agreements, retail contracts, joint venture agreements, EPC agreements, operation and maintenance agreements, service agreements, settlement agreements, and other types of contractual agreements with vendors and other third parties, as well as affiliates. These contracts generally indemnify the counterparty for tax, environmental liability, litigation and other matters, as well as breaches of representations, warranties and covenants set forth in these agreements. The Company is obligated with respect to customer deposits associated with the Company's retail operations. In some cases, NRG's maximum potential liability cannot be estimated, since the underlying agreements contain no limits on potential liability.

The following table summarizes the maximum potential exposures that can be estimated for NRG's guarantees, indemnities, and other contingent liabilities by maturity:

			By Remaining Maturity at December 31,
(In millions)			2024
Guarantees			Under 1 Year						1-3 Years						3-5 Years						Over 5 Years						Total						2023 Total
Letters of credit and surety bonds			$	3,996					$	181					$	11					$	—					$	4,188					$	4,592
Asset sales guarantee obligations			11						20						18						53						102						126
Other guarantees			—						—						—						27						27						27
Total guarantees			$	4,007					$	201					$	29					$	80					$	4,317					$	4,745

Letters of credit and surety bonds — As of December 31, 2024, NRG and its consolidated subsidiaries were contingently obligated for a total of $ 4.2 billion under letters of credit and surety bonds. Most of these letters of credit and surety bonds are issued in support of the Company's obligations to perform under commodity agreements and obligations associated with future closure and maintenance of ash sites, as well as for financing or other arrangements. A majority of these letters of credit and surety bonds expire within one year of issuance, and it is typical for the Company to renew them on similar terms.

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The material indemnities, within the scope of ASC 460, are as follows:

Asset sales — The purchase and sale agreements which govern NRG's asset or share investments and divestitures customarily contain guarantees and indemnifications of the transaction to third parties. The contracts indemnify the parties for liabilities incurred as a result of a breach of a representation or warranty by the indemnifying party, changes in tax laws or for pre-existing environmental matters. These obligations generally have a discrete term and are intended to protect the parties against risks that are difficult to predict or estimate at the time of the transaction. In several cases, the contract limits the liability of the indemnifier. NRG has no reason to believe that the Company currently has any material liability relating to such routine indemnification obligations included in the table above, except for the California property tax indemnity for estimated increases in California property taxes of certain solar properties that the Company agreed to indemnify, as part of the agreement to sell NRG Yield and the Renewables Platform. The California property tax indemnity is estimated to be $ 102 million as of December 31, 2024 and is included in the above table under asset sales guarantee obligations.

Other guarantees — NRG has issued other guarantees of obligations including payments under certain agreements with respect to certain of its unconsolidated subsidiaries, payment or performance by fuel providers and payment or reimbursement of credit support and deposits. The Company does not believe that it will be required to perform under these guarantees.

Other indemnities — Other indemnifications NRG has provided cover operational, tax, litigation and breaches of representations, warranties and covenants. NRG has also indemnified, on a routine basis in the ordinary course of business, consultants or other vendors who have provided services to the Company. NRG's maximum potential exposure under these indemnifications can range from a specified dollar amount to an indeterminate amount, depending on the nature of the transaction. Total maximum potential exposure under these indemnifications is not estimable due to uncertainty as to whether claims will be made or how they will be resolved. NRG does not have any reason to believe that the Company will be required to make any material payments under these indemnity provisions.

Because many of the guarantees and indemnities NRG issues to third parties and affiliates do not limit the amount or duration of its obligations to perform under them, there exists a risk that the Company may have obligations in excess of the amounts described above. For those guarantees and indemnities that do not limit the Company's liability exposure, it may not be able to estimate what the Company's liability would be, until a claim is made for payment or performance, due to the contingent nature of these contracts.

NRG owns an undivided interest in Cedar Bayou. Cedar Bayou is maintained and operated pursuant to its joint ownership participation and operating agreement. NRG is responsible for its subsidiary’s share of operating costs and direct expenses and includes its proportionate share of the facility and related revenues and direct expenses in the jointly-owned plant in the corresponding balance sheet and income statement captions of the Company's consolidated financial statements.

The following table summarizes NRG's proportionate ownership interest in the Company's jointly-owned facility:

(In millions unless otherwise stated)
As of December 31, 2024			Ownership Interest						Property, Plant & Equipment						Accumulated Depreciation						Construction in Progress
Cedar Bayou Unit 4, Baytown, TX			50.00		%				$	222					$	( 125 )					$	5

The components of accrued expenses and other current liabilities are as follows:

			Year Ended December 31,
(In millions)			2024						2023
Accrued RECs			$	477					$	435
Accrued compensation and employee benefits			514						452
Other			1,040						755
Total accrued expenses and other current liabilities			$	2,031					$	1,642

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SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS

For the Years Ended December 31, 2024, 2023 and 2022

(In millions)			Balance at Beginning of Period						Charged to Costs and Expenses						Charged to Other Accounts						Deductions						Balance at End of Period
Allowance for credit losses, deducted from accounts receivable and other non-current assets
Year Ended December 31, 2024			$	145					$	314					$	18					$	( 325 )		(a)			$	152
Year Ended December 31, 2023			133						251						35						( 274 )			(a)			145
Year Ended December 31, 2022			683						11						—						( 561 )			(a)			133
Income tax valuation allowance, deducted from deferred tax assets
Year Ended December 31, 2024			$	275					$	( 131 )					$	—					$	—					$	144
Year Ended December 31, 2023			224						42						9						—						275
Year Ended December 31, 2022			248						( 20 )						( 4 )						—						224

(a) Represents principally net amounts charged as uncollectible

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