0001013871-23-000004 | 10-K | XBRL Viewer

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Cover - USD ($)	12 Months Ended
Cover - USD ($)	Dec. 31, 2022	Feb. 15, 2023	Jun. 30, 2022
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	001-15891
Entity Registrant Name	NRG Energy, Inc
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	41-1724239
Entity Address, Address Line One	910 Louisiana Street
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	713
Local Phone Number	537-3000
Title of 12(b) Security	Common Stock, par value $0.01
Trading Symbol	NRG
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 6,461,030,777
Entity Common Stock, Shares Outstanding		229,774,238
Documents Incorporated by Reference	Portions of the Registrant's definitive Proxy Statement relating to its 2023 Annual Meeting of Stockholdersare incorporated by reference into Part III of this Annual Report on Form 10-K
Entity Central Index Key	0001013871
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	FY

Audit Information	12 Months Ended
Audit Information	Dec. 31, 2022
Audit Information [Abstract]
Auditor Name	KPMG LLP
Auditor Location	Philadelphia, PA
Auditor Firm ID	185

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenues
Total revenues	$ 31,543	$ 26,989	$ 9,093
Operating Costs and Expenses
Cost of operations (excluding depreciation and amortization shown below)	27,446	20,482	6,540
Depreciation and amortization	634	785	435
Impairment losses	206	544	75
Selling, general and administrative costs	1,228	1,293	810
Provision for credit losses	11	698	108
Acquisition-related transaction and integration costs	52	93	23
Total operating costs and expenses	29,577	23,895	7,991
Gain on sale of assets	52	247	3
Operating Income	2,018	3,341	1,105
Other Income/(Expense)
Equity in earnings of unconsolidated affiliates	6	17	17
Impairment losses on investments	0	0	(18)
Other income, net	56	63	67
Loss on debt extinguishment	0	(77)	(9)
Interest expense	(417)	(485)	(401)
Total other expense	(355)	(482)	(344)
Income Before Income Taxes	1,663	2,859	761
Income tax expense	442	672	251
Net Income	$ 1,221	$ 2,187	$ 510
Income Per Share
Weighted average number of common shares outstanding — basic (in shares)	236,000,000	245,000,000	245,000,000
Net Income per Weighted Average Common Share - Basic (in usd per share)	$ 5.17	$ 8.93	$ 2.08
Weighted average number of common shares outstanding — diluted (in shares)	236,000,000	245,000,000	246,000,000
Income per weighted average common share — diluted (in usd per share)	$ 5.17	$ 8.93	$ 2.07

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Comprehensive Income [Abstract]
Net Income	$ 1,221	$ 2,187	$ 510
Other Comprehensive (Loss)/Income, net of tax
Foreign currency translation adjustments	(35)	(5)	8
Defined benefit plans	(16)	85	(22)
Other comprehensive (loss)/income	(51)	80	(14)
Comprehensive Income	$ 1,170	$ 2,267	$ 496

- Definition

Amount after tax of increase (decrease) in equity from transactions and other events and circumstances from net income and other comprehensive income. Excludes changes in equity resulting from investments by owners and distributions to owners.

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- Definition

Amount after tax and reclassification adjustments of other comprehensive income (loss).

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CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Current Assets
Cash and cash equivalents	$ 430	$ 250
Funds deposited by counterparties	1,708	845
Restricted cash	40	15
Accounts receivable, net	4,773	3,245
Uplift securitization proceeds receivable from ERCOT	0	689
Inventory	751	498
Derivative instruments	7,886	4,613
Cash collateral paid in support of energy risk management activities	260	291
Prepayments and other current assets	383	395
Total current assets	16,231	10,841
Property, plant and equipment, net	1,692	1,688
Other Assets
Equity investments in affiliates	133	157
Operating lease right-of-use assets, net	225	271
Goodwill	1,650	1,795
Intangible assets, net	2,132	2,511
Nuclear decommissioning trust fund	838	1,008
Derivative instruments	4,108	2,527
Deferred income taxes	1,881	2,155
Other non-current assets	256	229
Total other assets	11,223	10,653
Total Assets	29,146	23,182
Current Liabilities
Current portion of long-term debt and finance leases	63	4
Current portion of operating lease liabilities	83	81
Accounts payable	3,643	2,274
Derivative instruments	6,195	3,387
Cash collateral received in support of energy risk management activities	1,708	845
Accrued expenses and other current liabilities	1,290	1,324
Total current liabilities	12,982	7,915
Other Liabilities
Long-term debt and finance leases	7,976	7,966
Non-current operating lease liabilities	180	236
Nuclear decommissioning reserve	340	321
Nuclear decommissioning trust liability	477	666
Derivative instruments	2,246	1,412
Deferred income taxes	134	73
Other non-current liabilities	983	993
Total other liabilities	12,336	11,667
Total Liabilities	25,318	19,582
Commitments and Contingencies
Stockholders' Equity
Common stock; $0.01 par value; 500,000,000 shares authorized; 423,897,001 and 423,547,174 shares issued; and 229,561,030 and 243,753,899 shares outstanding at December 31, 2022 and 2021, respectively	4	4
Additional paid-in capital	8,457	8,531
Retained earnings	1,408	464
Treasury stock, at cost; 194,335,971 and 179,793,275 shares at December 31, 2022 and 2021, respectively	(5,864)	(5,273)
Accumulated other comprehensive loss	(177)	(126)
Total Stockholders' Equity	3,828	3,600
Total Liabilities and Stockholders' Equity	$ 29,146	$ 23,182

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Common stock, par value (in usd per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	500,000,000	500,000,000
Common stock, shares issued (in shares)	423,897,001	423,547,174
Common stock, shares outstanding (in shares)	229,561,030	243,753,899
Treasury stock, shares (in shares)	194,335,971	179,793,275

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Cash Flows from Operating Activities
Net income	$ 1,221	$ 2,187	$ 510
Adjustments to reconcile net income to net cash provided by operating activities:
Distributions from and equity in earnings of unconsolidated affiliates	7	20	45
Depreciation and amortization	634	785	435
Accretion of asset retirement obligations	55	30	45
Provision for credit losses	11	698	108
Amortization of nuclear fuel	54	51	54
Amortization of financing costs and debt discounts	23	39	48
Loss on debt extinguishment	0	77	9
Amortization of in-the-money contracts and emission allowances	158	106	70
Amortization of unearned equity compensation	28	21	22
Net gain on sale of assets and disposal of assets	(102)	(261)	(23)
Impairment losses	206	544	93
Changes in derivative instruments	(3,221)	(3,626)	137
Changes in deferred income taxes and liability for uncertain tax benefits	382	604	228
Changes in collateral deposits in support of risk management activities	896	797	127
Changes in nuclear decommissioning trust liability	9	40	51
Oil lower of cost or market adjustment	0	0	29
Uplift securitization proceeds received/(receivable) from ERCOT	689	(689)	0
Cash (used)/provided by changes in other working capital, net of acquisition and disposition effects:
Accounts receivable - trade	(1,560)	(1,232)	0
Inventory	(252)	(61)	27
Prepayments and other current assets	17	31	4
Accounts payable	1,295	476	(56)
Accrued expenses and other current liabilities	(29)	(55)	(42)
Other assets and liabilities	(161)	(89)	(84)
Cash provided by operating activities	360	493	1,837
Cash Flows from Investing Activities
Payments for acquisitions of assets, businesses and leases	(62)	(3,559)	(284)
Capital expenditures	(367)	(269)	(230)
Net purchases of emissions allowances	(6)	0	(10)
Investments in nuclear decommissioning trust fund securities	(454)	(751)	(492)
Proceeds from sales of nuclear decommissioning trust fund securities	448	710	439
Proceeds from sale of assets, net of cash disposed and fees	109	830	81
Changes in investments in unconsolidated affiliates	0	0	2
Cash used by investing activities	(332)	(3,039)	(494)
Cash Flows from Financing Activities
Net receipts/(payments) from settlement of acquired derivatives that include financing elements	1,995	938	(7)
Payments for share repurchase activity	(606)	(48)	(229)
Payments of dividends to common stockholders	(332)	(319)	(295)
Proceeds from issuance of long-term debt	0	1,100	3,234
Payments for short and long-term debt	(5)	(1,861)	(335)
Payments for debt extinguishment costs	0	(65)	(5)
Payments of debt issuance costs	(9)	(18)	(75)
Repayments of Revolving Credit Facility	0	0	(83)
Proceeds from issuance of common stock	0	1	1
Purchase of and distributions to noncontrolling interests from subsidiaries	0	0	(2)
Cash provided/(used) by financing activities	1,043	(272)	2,204
Effect of exchange rate changes on cash and cash equivalents	(3)	(2)	(2)
Net Increase/(Decrease) in Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash	1,068	(2,820)	3,545
Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash at Beginning of Period	1,110	3,930	385
Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash at End of Period	$ 2,178	$ 1,110	$ 3,930

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($)
$ in Millions

Total

Cumulative Effect, Period of Adoption, Adjustment

Common Stock

Additional Paid-In Capital

Cumulative Effect, Period of Adoption, Adjustment

Retained Earnings/ (Accumulated Deficit)

Cumulative Effect, Period of Adoption, Adjustment

Treasury Stock

Accumulated Other Comprehensive Loss

Beginning balance at Dec. 31, 2019

$ 1,658

$ 4

$ 8,501

$ (1,616)

$ (5,039)

$ (192)

Increase (Decrease) in Stockholders' Equity

Net income

510

Other comprehensive loss

(14)

Repurchase of partners' equity interest in VIE

Shares reissuance for ESPP

Share repurchases

(197)

Equity-based awards activity, net

^[1]

(3)

Issuance of common stock

Common stock dividends and dividend equivalents declared

^[2]

(297)

Ending balance at Dec. 31, 2020

1,680

8,517

(1,403)

(5,232)

(206)

Increase (Decrease) in Stockholders' Equity

Net income

2,187

Other comprehensive loss

Shares reissuance for ESPP

Share repurchases

(44)

Equity-based awards activity, net

^[1]

Issuance of common stock

Common stock dividends and dividend equivalents declared

^[2]

(320)

Ending balance at Dec. 31, 2021

$ 3,600

$ (43)

8,531

$ (100)

464

$ 57

(5,273)

(126)

Increase (Decrease) in Stockholders' Equity

Accounting Standards Update [Extensible Enumeration]

Accounting Standards Update 2020-06 [Member]

Net income

$ 1,221

1,221

Other comprehensive loss

(51)

Shares reissuance for ESPP

Share repurchases

(595)

Equity-based awards activity, net

^[1]

Common stock dividends and dividend equivalents declared

^[2]

(334)

Ending balance at Dec. 31, 2022

$ 3,828

$ 4

$ 8,457

$ 1,408

$ (5,864)

$ (177)

[1]	Includes $(6) million, $(9) million and $(27) million of equivalent shares purchased in lieu of tax withholding on equity compensation issuances for the years ended December 31, 2022, 2021 and 2020, respectively
[2]	Dividends per common share were $1.40, $1.30 and $1.20 for each of the years ended December 31, 2022, 2021 and 2020, respectively

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - $ / shares shares in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Stockholders' Equity [Abstract]
Shares purchased in lieu of tax withholding (in shares)	(6)	(9)	(27)
Dividends paid per share (in usd per share)	$ 1.40	$ 1.30	$ 1.20

Nature of Business	12 Months Ended
Nature of Business	Dec. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	Nature of Business General NRG Energy, Inc., or NRG or the Company, is a consumer services company built on dynamic retail brands. NRG brings the power of energy to customers by producing and selling energy and related products and services, nation-wide in the U.S. and Canada in a manner that delivers value to all of NRG's stakeholders. NRG sells power, natural gas, home and power services, and develops innovative, sustainable solutions, predominately under the brand names NRG, Reliant, Direct Energy, Green Mountain Energy, Stream, and XOOM Energy. The Company has a customer base that includes approximately 5.4 million Home customers as well as commercial, industrial, and wholesale customers, supported by approximately 16 GW of generation. On December 6, 2022, NRG and Vivint Smart Home, Inc. announced the entry into a definitive agreement under which the Company will acquire Vivint, a smart home platform company, in an all-cash transaction. The acquisition will accelerate the realization of NRG’s consumer-focused growth strategy and create a leading essential home services platform fueled by market-leading brands, unparalleled insights, proprietary technologies and complementary sales channels. Close of the acquisition is targeted for the first quarter of 2023 and is subject to customary closing conditions. The Company manages its operations based on the combined results of the retail and wholesale generation businesses with a geographical focus. The Company's business is segmented as follows: •Texas, which includes all activity related to customer, plant and market operations in Texas; •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, (ii) the Services businesses (iii) activity related to the Cottonwood facility, (iv) the remaining renewables activity, including the Company’s equity method investment in Ivanpah Master Holdings, LLC, and (v) activity related to the Company’s equity method investment for the Gladstone power plant in Australia; and •Corporate activities.

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2022

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

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.

Winter Storm Uri Uplift Securitization Proceeds

The Texas Legislature passed HB 4492 in May 2021 for ERCOT to mitigate exceptionally high price adders and ancillary service costs incurred by 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 ORDPA 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. The Company received proceeds of $689 million from ERCOT in June 2022.

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. 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.

The following table represents the activity in the allowance for credit losses for the years ended December 31, 2022, 2021, and 2020:


	Year Ended December 31,
(In millions)	2022		2021		2020
Beginning balance	$	683	$	67	$	43
Acquired balance from Direct Energy	—		112		—
Provision for credit losses(a)	11		698		108
Write-offs	(593)		(224)		(101)
Recoveries collected	32		30		17
Ending balance(a)	$	133	$	683	$	67

(a)Includes bilateral finance hedging risk of $(70) million and $403 million accounted for under ASC 815 for the years ended December 31, 2022 and December 31, 2021, 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. During the year ended December 31, 2021, the provision for credit losses included $596 million of expense due to the impacts of Winter Storm Uri. The increase in write-offs for the periods ended December 31, 2022 and 2021 were 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. 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)	2022		2021		2020
Cash and cash equivalents	$	430	$	250	$	3,905
Funds deposited by counterparties	1,708		845		19
Restricted cash	40		15		6
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$	2,178	$	1,110	$	3,930

Restricted cash consists primarily of funds held to satisfy the requirements of certain financing agreements and 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. Spare parts inventory is valued at weighted average cost. The Company removes these 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 these inventories as they are sold to customers. 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, fair value; however, impairment adjustments are recorded whenever events or changes in circumstances indicate that their carrying values may not be recoverable. NRG also classifies nuclear fuel related to the Company's 44% ownership interest in STP as part of the Company's property, plant, and equipment. 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 is 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.

Business Interruption Insurance

The Company carries insurance policies to cover insurable risks including, but not limited to, business interruption. As a result of damage at the Limestone 1 and W.A. Parish 8 units, the Company recorded business interruption insurance settlements of $81 million during the year ended December 31, 2022. 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 11, 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 emission allowances, customer and supply contracts, customer relationships, marketing partnerships, 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, 2022 and 2021, the Company had accumulated amortization related to its intangible assets of $2.1 billion and $1.6 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.

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.

The Company first assesses 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 11, Asset Impairments.

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 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 20, Income Taxes, changes to existing net deferred tax assets or valuation allowances or changes to uncertain tax benefits, are recorded to income tax (benefit)/expense.

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, 2022, 2021, and 2020, the Company's revenues and cost of operations included gross receipts taxes of $218 million, $184 million, and $107 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 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, $202 million, $189 million, and $98 million as of December 31, 2022, 2021, and 2020, 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 ERCOT ISO settlements. Volume estimates are then multiplied by the supply rate and recorded as cost of operations in the applicable reporting period.

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 and other energy related commodities used to mitigate variability in earnings due to fluctuation in market prices. 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, 2022 and 2021 the Company did not have derivative instruments that were designated as cash flow or fair value hedge.

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/(expense) in the Company's consolidated statements of operations. For the years ended December 31, 2022, amounts recognized as foreign currency transaction losses were $(7) million. For the years ended December 31, 2021 and 2020, amounts recognized as foreign currency transaction gains/(losses) were immaterial. The Company's cumulative translation adjustment balances as of December 31, 2022, 2021, and 2020 were $55 million, $(8) million, and $(2) million, respectively.

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.

Fair Value of Financial Instruments

The carrying amount of cash and cash equivalents, funds deposited by counterparties, receivables, accounts payable, and accrued liabilities approximate fair value because of the short-term maturity of these instruments. See Note 5, Fair Value of Financial Instruments, for a further discussion of fair value of financial instruments.

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 14, 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.

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. The fair value of the Company's restricted stock units is derived from the closing price of NRG's common stock at the grant date. 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.

Investments Accounted for by the Equity Method

The Company has investments in various 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.

Tax Equity Arrangements

The Company’s redeemable noncontrolling interest in subsidiaries represented third-party interests in the net assets under certain tax equity arrangements, which were consolidated by the Company, that had been entered into to finance the cost of solar energy systems under operating leases. The amounts reported as redeemable noncontrolling interests represented the amounts the investors that were party to the tax equity arrangements would hypothetically receive at each balance sheet date under the liquidation provisions of the contractual agreements, assuming the net assets of the funding structures were liquidated at their recorded amounts. During the first quarter of 2020, the Company repurchased its partners' equity interest, which was the Company's last remaining tax equity arrangement.

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. See Note 10, Leases, for further discussion.

Marketing and Advertising Costs

The Company expenses its marketing and advertising costs as incurred and includes them within selling, general and administrative expenses. 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, 2022, 2021, and 2020 were $82 million, $109 million, and $74 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 2022

ASU 2020-06 — In August 2020, the FASB issued ASU No. 2020-06, Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity’s Own Equity (Subtopic 815-40), or ASU 2020-06. The guidance in ASU 2020-06 reduces the number of accounting models for convertible debt instruments and convertible preferred stock. In addition, ASU 2020-06 improves and amends the related earnings per share guidance. The Company adopted this standard on January 1, 2022 using the modified retrospective approach. As a result of the provisions of the amended guidance, the Company recorded a $100 million decrease to additional paid-in capital, a $57 million decrease to debt discount, a $57 million increase to retained earnings, and a $14 million decrease to long-term deferred tax liabilities. The adoption of ASU 2020-06 did not have a material impact on the Company's statements of operations, statements of cash flows or earnings per share amounts.

Recent Accounting Developments - Guidance Not Yet Adopted

ASU 2021-08 — In October 2021, the FASB issued ASU No. 2021-08, Business Combinations (Topic 805): Accounting for Contract Assets and Contract Liabilities from Contracts with Customers, or ASU 2021-08. Under current GAAP, an acquirer generally recognizes assets acquired and liabilities assumed in a business combination, including contract assets and contract liabilities arising from revenue contracts with customers and other similar contracts that are accounted for in accordance with ASC 606, Revenue from Contracts with Customers, or ASC 606, at fair value on the acquisition date. ASU 2021-08 requires that an entity recognize and measure contract assets and contract liabilities acquired in a business combination in accordance with ASC 606. At the acquisition date, an acquirer should account for the related revenue contracts in accordance with ASC 606 as if it had originated the contracts, which should generally result in an acquirer recognizing and measuring the acquired contract assets and contract liabilities consistent with how they were recognized and measured in the acquiree’s financial statements. This update also provides certain practical expedients for acquirers when recognizing and measuring acquired contract assets and contract liabilities from revenue contracts in a business combination. The amendments in this update are effective for fiscal years beginning after December 15, 2022, including interim periods within those fiscal years and should be applied prospectively to business combinations occurring on or after the effective date of the amendments. The Company will evaluate the impacts of the amendments for business combinations occurring after the effective date.

Revenue Recognition

12 Months Ended

Dec. 31, 2022

Revenue from Contract with Customer [Abstract]

Revenue Recognition

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. 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.

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. 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, ISO-NE 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. 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, 2022, estimated future fixed fee performance obligations are $77 million, $23 million, and $2 million for fiscal years 2023, 2024, and 2025, respectively. These performance obligations are for cleared auction MWs in the PJM, NYISO and MISO capacity auctions and are subject to penalties for non-performance.

Disaggregated Revenue

The following tables represent the Company’s disaggregation of revenue from contracts with customers for the years ended December 31, 2022, 2021, and 2020:


	For the Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	6,388	$	2,088	$	2,286	$	(1)	$	10,761
Business	3,229		13,768		1,964		—		18,961
Total retail revenue(b)	9,617		15,856		4,250		(1)		29,722
Energy revenue(b)	111		641		466		32		1,250
Capacity revenue(b)	—		232		40		—		272
Mark-to-market for economic hedging activities(c)	2		(30)		(56)		1		(83)
Contract amortization	—		(40)		1		—		(39)
Other revenue(b)	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) Home includes Services
(b) The following amounts of retail, energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(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)
(c) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815


	For the Year Ended December 31, 2021
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	5,659	$	1,832	$	2,059	$	(1)	$	9,549
Business	2,745		10,030		1,237		—		14,012
Total retail revenue	8,404		11,862		3,296		(1)		23,561
Energy revenue(c)	329		508		371		7		1,215
Capacity revenue(c)	—		718		57		—		775
Mark-to-market for economic hedging activities(d)	(3)		(88)		(86)		13		(164)
Contract amortization	—		(26)		(4)		—		(30)
Other revenue(b)(c)	1,565		51		25		(9)		1,632
Total revenue	10,295		13,025		3,659		10		26,989
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		(25)		3		—		(22)
Less: Realized and unrealized ASC 815 revenue	130		184		(96)		16		234
Total revenue from contracts with customers	$	10,165	$	12,866	$	3,752	$	(6)	$	26,777
(a) Home includes Services
(b) Other Revenue in Texas includes ancillary revenues of $1.3 billion driven by high pricing during Winter Storm Uri
(c) The following amounts of energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Energy revenue	$	—	$	131	$	2	$	3	$	136
Capacity revenue	—		149		—		—		149
Other revenue	133		(8)		(12)		—		113
(d) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815


	For the Year Ended December 31, 2020
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	5,020	$	1,210	$	103	$	(2)	$	6,331
Business	1,034		95		—		—		1,129
Total retail revenue	6,054		1,305		103		(2)		7,460
Energy revenue(b)	24		183		333		(1)		539
Capacity revenue(b)	—		620		61		(1)		680
Mark-to-market for economic hedging activities(c)	2		88		(3)		8		95
Contract amortization	—		—		—		—		—
Other revenue(b)	232		53		42		(8)		319
Total revenue	6,312		2,249		536		(4)		9,093
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		1		17		—		18
Less: Realized and unrealized ASC 815 revenue	30		314		38		3		385
Total revenue from contracts with customers	$	6,282	$	1,934	$	481	$	(7)	$	8,690
(a) Home includes Services
(b) The following amounts of energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Energy revenue	$	—	$	67	$	43	$	(5)	$	105
Capacity revenue	—		156		—		—		156
Other revenue	28		3		(2)		—		29
(c) 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, 2022 and 2021:


(In millions)	December 31, 2022		December 31, 2021
Deferred customer acquisition costs	$	126	$	133

Accounts receivable, net - Contracts with customers	4,704		3,057
Accounts receivable, net - Accounted for under topics other than ASC 606	64		182
Accounts receivable, net - Affiliate	5		6
Total accounts receivable, net	$	4,773	$	3,245

Unbilled revenues (included within Accounts receivable, net - Contracts with customers)	$	1,952	$	1,574

Deferred revenues (a)	$	186	$	227

(a) Deferred revenues from contracts with customers for the years ended December 31, 2022 and 2021 were approximately $175 million and $224 million, respectively

The revenue recognized from contracts with customers during the years ended December 31, 2022 and 2021 relating to the deferred revenue balance at the beginning of each period was $184 million and $23 million, respectively. The change in deferred revenue balances during the years ended December 31, 2022 and 2021 was primarily due to the usage of customer bill credits by certain C&I customers, which were as a result of power pricing during Winter Storm Uri.

The Company's customer acquisition costs consist of broker fees, commission payments and other costs that represent incremental costs of obtaining the contract with customers for which the Company expects to recover. The Company amortizes these amounts over the estimated life of the customer contract. As a practical expedient, the Company expenses the incremental costs of obtaining a contract if the amortization period of the asset would have been one year or less.

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. Generally, the Company will recognize revenue from contract liabilities in the next period as the Company satisfies its performance obligations.

- Definition

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-URI https://asc.fasb.org/topic&trid=49130388

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 10
-URI https://asc.fasb.org/extlink&oid=126920106&loc=SL49130551-203045

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 13
-Subparagraph (b)(2)
-URI https://asc.fasb.org/extlink&oid=126920106&loc=SL49130556-203045

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (b)
-URI https://asc.fasb.org/extlink&oid=126920106&loc=SL49130554-203045

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 9
-URI https://asc.fasb.org/extlink&oid=126920106&loc=SL49130550-203045

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (e)
-URI https://asc.fasb.org/extlink&oid=126920106&loc=SL49130554-203045

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (a)
-URI https://asc.fasb.org/extlink&oid=126920106&loc=SL49130554-203045

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (d)
-URI https://asc.fasb.org/extlink&oid=126920106&loc=SL49130554-203045

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 15
-URI https://asc.fasb.org/extlink&oid=126920106&loc=SL49130558-203045

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (c)
-URI https://asc.fasb.org/extlink&oid=126920106&loc=SL49130554-203045

+ Details

Acquisitions and Dispositions

12 Months Ended

Dec. 31, 2022

Discontinued Operations and Disposal Groups [Abstract]

Acquisitions and Dispositions

Acquisitions

2023 Anticipated Acquisition

Vivint Smart Home Acquisition

On December 6, 2022, the NRG and Vivint Smart Home, Inc. announced the entry into a definitive merger agreement under which the Company will acquire Vivint, a smart home platform company, in an all-cash transaction. The acquisition will accelerate the realization of NRG's consumer-focused growth strategy and create a leading essential home services platform fueled by market-leading brands, unparalleled insights, proprietary technologies and complementary sales channels. Close of the acquisition is targeted for the first quarter of 2023 and is subject to customary closing conditions. The Company will pay $12 per share, or approximately $2.8 billion in cash, and expects to fund the acquisition using proceeds from newly issued debt and preferred equity, drawing on its Revolving Credit Facility and Receivables Securitization Facilities, and through cash on hand. Additionally, in the first quarter of 2023, NRG increased its Revolving Credit Facility by $600 million to meet the additional liquidity requirements related to the acquisition. For further discussion see Note 13, Long-term Debt and Finance Leases.

In connection with the merger agreement, NRG entered into a commitment letter for a senior secured 364-day bridge term loan facility in a principal amount not to exceed $2.1 billion for the purposes of financing the Vivint acquisition, paying fees and expenses in connection with the acquisition, and certain other third-party payments in respect of arrangements of Vivint.

Acquisition costs of $17 million for the year ended December 31, 2022 are included in acquisition-related transaction and integration costs in the Company's Consolidated Statement of operations.

2021 Acquisitions

Direct Energy Acquisition

On January 5, 2021, the Company acquired all of the issued and outstanding common shares of Direct Energy, which had been a North American subsidiary of Centrica. Direct Energy is a leading retail provider of electricity, natural gas, and home and business energy related products and services in North America, with operations in all 50 U.S. states and 8 Canadian provinces. The acquisition increased NRG's retail portfolio by over 3 million customers and strengthened its integrated model. It also broadened the Company's presence in the Northeast and into states and locales where it did not previously operate, supporting NRG's objective to diversify its business.

The Company paid an aggregate purchase price of $3.625 billion in cash and total purchase price adjustment of $99 million, resulting in an adjusted purchase price of $3.724 billion.

Acquisition costs of $25 million and $17 million for the years ended December 31, 2021 and 2020, 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 acquired and liabilities assumed recorded at their estimated fair values on the acquisition date. The purchase price was allocated as follows as of December 31, 2021:


	(In millions)
Current Assets
Cash and cash equivalents	$	152
Funds deposited by counterparties	21
Restricted cash	9
Accounts receivable, net	1,802
Inventory	106
Derivative instruments	1,014
Cash collateral paid in support of energy risk management activities	233
Prepayments and other current assets	173
Total current assets	3,510


	(In millions)
Property, plant and equipment, net	151
Other Assets
Goodwill(a)	1,250
Intangible assets, net:
Customer relationships(b)	1,277
Customer and supply contracts(b)	610
Trade names(b)	310
Renewable energy credits	124
Total intangible assets, net	2,321
Derivative instruments	531
Other non-current assets	31
Total other assets	4,133
Total Assets	$	7,794

Current Liabilities
Accounts payable	$	1,116
Derivative instruments	1,266
Cash collateral received in support of energy risk management activities	21
Accrued expenses and other current liabilities	670
Total current liabilities	3,073
Other Liabilities
Derivative instruments	562
Deferred income taxes	320
Other non-current liabilities	115
Total other liabilities	997
Total Liabilities	$	4,070

Direct Energy Purchase Price	$	3,724

(a)Goodwill arising from the acquisition was attributed to the value of the platform acquired and the synergies expected from combining the operations of Direct Energy with NRG's existing businesses. Goodwill was allocated to the Texas, East, and West/Services/Other segments of $427 million, $648 million and $175 million, respectively. Goodwill deductible for tax purposes was $322 million

(b)As of January 5, 2021, the weighted average amortization period for total amortizable intangible assets was 12 years

2020 Acquisitions

Midwest Generation Lease Purchase

On September 29, 2020, Midwest Generation acquired all of the ownership interests in the Powerton facility and Units 7 and 8 of the Joliet facility, which were being leased through 2034 and 2030, respectively, for approximately $260 million. The purchase was funded with cash-on-hand. Upon closing, lease expense related to these facilities, which totaled approximately $14 million in 2019, and the operating lease liability of $148 million were eliminated.

Dispositions

2023 Dispositions

Sale of Astoria

On January 6, 2023, the Company closed on the sale of land and related assets from the Astoria site, within the East region of operations, for initial proceeds of $212 million, subject to transaction fees of $3 million and certain indemnifications. As part of the transaction, NRG entered into an agreement to lease the land back for the purpose of operating the Astoria gas turbines through the planned April 30, 2023 retirement date. The operating lease agreement is expected to end six months after the facility's actual retirement date.

2022 Dispositions

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.

2021 Dispositions

Sale of 4,850 MW of Fossil generating assets

On December 1, 2021, the Company closed the previously announced sale of approximately 4,850 MWs of fossil generating assets from its East and West regions to Generation Bridge, an affiliate of ArcLight Capital Partners. Proceeds of $760 million were reduced by working capital and other adjustments of $140 million, resulting in net proceeds of $620 million. The Company recorded a gain of $207 million from the sale, which includes the $39 million indemnification liability recorded as discussed below. As part of the transaction, NRG entered into a tolling agreement for the 866 MW Arthur Kill plant in New York City through April 2025.

As part of the agreement to sell the fossil generating assets, NRG has agreed to indemnify Generation Bridge for certain future environmental compliance costs up to $39 million. The indemnity term will expire on December 1, 2028. The Company has recorded the liability within accrued expenses and other current liabilities and other non-current liabilities.

Sale of Agua Caliente

On February 3, 2021, the Company closed on the sale of its 35% ownership in the Agua Caliente solar project to Clearway Energy, Inc. for $202 million. NRG recognized a gain on the sale of $17 million, including cash disposed of $7 million.

2020 Dispositions

Sale of Home Solar

In the third quarter of 2020, the Company concluded its Home Solar business was held for sale and recorded an impairment loss of $29 million, as further discussed in Note 11, Asset Impairments. On November 13, 2020, the Company completed the sale of the Home Solar business for cash proceeds of $66 million, resulting in a $2 million loss on the sale. In connection with the sale, the Company extinguished debt of $27 million and recognized a $5 million loss on the extinguishment.

Fair Value of Financial Instruments

12 Months Ended

Dec. 31, 2022

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

For cash and cash equivalents, funds deposited by counterparties, restricted cash, accounts and other receivables, accounts payable, restricted cash, 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,
	2022				2021
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value



Convertible Senior Notes	$	575	$	576	$	518	$	677
Other long-term debt, including current portion	7,523		6,432		7,522		7,650
Total long-term debt, including current portion (a)	$	8,098	$	7,008	$	8,040	$	8,327

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

The fair value of the Company's long-term debt is based on quoted market prices and is 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.

Recurring Fair Value Measurements

Debt securities, equity securities, and trust fund investments, which are comprised of various U.S. debt and equity securities, and derivative assets and liabilities, 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, 2022
	Fair Value
(In millions)	Total		Level 1		Level 2		Level 3
Investments in securities (classified within other current and non-current assets)	$	19	$	—	$	19	$	—

Nuclear trust fund investments:
Cash and cash equivalents	15		15		—		—
U.S. government and federal agency obligations	86		84		2		—
Federal agency mortgage-backed securities	101		—		101		—
Commercial mortgage-backed securities	35		—		35		—
Corporate debt securities	114		—		114		—
Equity securities	403		403		—		—
Foreign government fixed income securities	1		—		1		—
Other trust fund investments (classified within other non-current assets):
U.S. government and federal agency obligations	1		1		—		—
Derivative assets:
Foreign exchange contracts	18		—		18		—
Commodity contracts	11,976		1,929		8,796		1,251


Measured using net asset value practical expedient:
Equity securities - nuclear trust fund investments	83
Equity securities (classified within other non-current assets)	6
Total assets	$	12,858	$	2,432	$	9,086	$	1,251
Derivative liabilities:
Foreign exchange contracts	$	2	$	—	$	2	$	—
Commodity contracts	8,439		1,244		6,449		746

Total liabilities	$	8,441	$	1,244	$	6,451	$	746


	As of December 31, 2021
	Fair Value
(In millions)	Total		Level 1		Level 2		Level 3
Investments in securities (classified within other current or non-current assets)	$	32	$	15	$	17	$	—
Nuclear trust fund investments:
Cash and cash equivalents	33		33		—		—
U.S. government and federal agency obligations	112		111		1		—
Federal agency mortgage-backed securities	100		—		100		—
Commercial mortgage-backed securities	44		—		44		—
Corporate debt securities	122		—		122		—
Equity securities	494		494		—		—
Foreign government fixed income securities	4		—		4		—
Other trust fund investments (classified within other non-current assets):
U.S. government and federal agency obligations	1		1		—		—
Derivative assets:
Foreign exchange contracts	1		—		1		—
Commodity contracts	7,139		981		5,701		457


Measured using net asset value practical expedient:
Equity securities - nuclear trust fund investments	99
Equity securities (classified within other non-current assets)	7
Total assets	$	8,188	$	1,635	$	5,990	$	457
Derivative liabilities:
Foreign exchange contracts	$	1	$	—	$	1	$	—
Commodity contracts	4,798		626		4,008		164

Total liabilities	$	4,799	$	626	$	4,009	$	164

The following table reconciles, for the years ended December 31, 2022 and 2021, the beginning and ending balances for financial instruments that are recognized at fair value in the consolidated financial statements using significant unobservable inputs:


	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Derivatives (a)
	For the Year Ended December 31,
(In millions)	2022		2021
Beginning balance	$	293	$	(16)
Contracts added from Direct Energy acquisition	—		(15)
Total gains realized/unrealized included in earnings	53		145

Purchases	(110)		93

Transfers into Level 3 (b)	264		71
Transfers out of Level 3 (b)	5		15
Ending balance	$	505	$	293
Gains 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	$	204	$	120

(a)Consists of derivatives assets and liabilities, net

(b)Transfers into/out of Level 3 are related to the availability of external broker quotes, and are valued as of the end of the reporting period. All transfers into/out of Level 3 are from/to Level 2

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

Non-derivative fair value measurements

The trust fund investments are held primarily to satisfy NRG's nuclear decommissioning obligations. These trust fund investments hold debt and equity securities directly and equity securities indirectly through commingled funds. The fair values of equity securities held directly by the trust funds are based on quoted prices in active markets and are categorized in Level 1. In addition, U.S. government and federal agency obligations are categorized as Level 1 because they trade in a highly liquid and transparent market. The fair values of corporate debt securities are based on evaluated prices that reflect observable market information, such as actual trade information of similar securities, adjusted for observable differences and are categorized in Level 2. Certain equity securities, classified as commingled funds, are analogous to mutual funds, are maintained by investment companies, and hold certain investments in accordance with a stated set of fund objectives. The fair value of the equity securities classified as commingled funds are based on net asset values per fund share (the unit of account), derived from the quoted prices in active markets of the underlying equity securities. However, because the shares in the commingled funds are not publicly quoted and not traded in an active market, the commingled funds are measured using net asset value practical expedient. See also Note 7, Nuclear Decommissioning Trust Fund.

Derivative fair value measurements

A portion of the Company's contracts are exchange-traded contracts with readily available quoted market prices. A majority of NRG's contracts are non-exchange-traded contracts valued using prices provided by external sources, primarily price quotations available through brokers or over-the-counter and on-line exchanges. For the majority of NRG markets, the Company receives quotes from multiple sources. To the extent that NRG receives multiple quotes, the Company's prices reflect the average of the bid-ask mid-point prices obtained from all sources that NRG believes provide the most liquid market for the commodity. If the Company receives one quote, then the mid-point of the bid-ask spread for that quote is used. The terms for which such price information is available vary by commodity, region and product. A significant portion of the fair value of the Company's derivative portfolio is based on price quotes from brokers in active markets who regularly facilitate those transactions and the Company believes such price quotes are executable. The Company does not use third-party sources that derive price based on proprietary models or market surveys. 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. Contracts valued with prices provided by models and other valuation techniques make up 10% of derivative assets and 9% 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 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 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, 2022, the credit reserve resulted in a $9 million decrease primarily within cost of operations. As of December 31, 2021, the credit reserve resulted in $11 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, 2022 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 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.

NRG's significant positions classified as Level 3 include physical and financial natural gas and power contracts executed in illiquid markets as well as financial transmission rights, or 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. For FTRs, NRG uses the most recent auction prices to derive the fair value.

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, 2022 and 2021:


	Significant Unobservable Inputs
	December 31, 2022
	Fair Value						Input/Range
(In millions)	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
Natural Gas Contracts	$	340	$	448	Discounted Cash Flow	Forward Market Price (per MMBtu)	$	2	$	48	$	6
Power Contracts	843		216		Discounted Cash Flow	Forward Market Price (per MWh)	3		431		48
FTRs	68		82		Discounted Cash Flow	Auction Prices (per MWh)	(32)		610		0
	$	1,251	$	746


	Significant Unobservable Inputs
	December 31, 2021
	Fair Value						Input/Range
(In millions)	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
Natural Gas Contracts	$	16	$	1	Discounted Cash Flow	Forward Market Price (per MMBtu)	$	3	$	40	$	15
Power Contracts	392		121		Discounted Cash Flow	Forward Market Price (per MWh)	3		212		35
FTRs	49		42		Discounted Cash Flow	Auction Prices (per MWh)	(122)		43		0
	$	457	$	164

The following table provides sensitivity of fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2022 and 2021:

Significant Unobservable Input

Position

Change In Input

Impact on Fair Value Measurement

Forward Market Price Natural Gas/ Power

Buy

Increase/(Decrease)

Higher/(Lower)

Forward Market Price Natural Gas/Power

Sell

Increase/(Decrease)

Lower/(Higher)

FTR Prices

Buy

Increase/(Decrease)

Higher/(Lower)

FTR Prices

Sell

Increase/(Decrease)

Lower/(Higher)

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, 2022, the Company recorded $260 million of cash collateral posted and $1.7 billion 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 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, 2022, counterparty credit exposure, excluding credit exposure from RTOs, ISOs, and registered commodity exchanges and certain long-term agreements, was $2.7 billion and NRG held collateral (cash and letters of credit) against those positions of $1.0 billion, resulting in a net exposure of $1.7 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 80% of the Company's exposure before collateral is expected to roll off by the end of 2024. 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	62	%
Financial institutions	38


Total	100	%


Category	Net Exposure (a) (b) (% of Total)
Investment grade	65	%
Non-Investment grade/Non-Rated	35

Total	100	%

(a)Counterparty credit exposure excludes uranium and 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 currently has no exposure to wholesale counterparties in excess of 10% of the total net exposure discussed above as of December 31, 2022. Changes in hedge positions and market prices will affect credit exposure and counterparty concentration.

During Winter Storm Uri, in February 2021, the Company experienced nonperformance by a counterparty in one of its bilateral financial hedging transactions, resulting in exposure of $403 million. During December 2022, the Company received $70 million as part of the Company's loss mitigation efforts related to this exposure.

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 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, 2022, aggregate credit risk exposure managed by NRG to these counterparties was approximately $1.1 billion for the next five years.

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, 2022, 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 $11 million, $698 million, and $108 million for the years ending December 31, 2022, 2021, and 2020, 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. During the year ended December 31, 2021, the provision for credit losses included $596 million of expenses due to the impacts of Winter Storm Uri.

- Definition

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References + Details

Accounting for Derivative Instruments and Hedging Activities

12 Months Ended

Dec. 31, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Accounting for Derivative Instruments and Hedging Activities

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 and foreign exchange contracts.

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.

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

•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, 2022, 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 2036;

•Forward and financial contracts for the purchase of fuel commodities relating to the forecasted usage of NRG's generation assets through 2024;

•Other energy derivatives instruments extending through 2029.

Also, as of December 31, 2022, 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 2036;

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

•Power tolling contracts through 2038;

•Coal purchase contracts through 2024;

•Power transmission contracts through 2028;

•Natural gas transportation contracts through 2034;

•Natural gas storage agreements through 2027; 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 2026.

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, 2022 and 2021. 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.


(In millions)		Total Volume
Commodity	Units	December 31, 2022	December 31, 2021
Emissions	Short Ton	1	1
Renewables Energy Certificates	Certificates	15	13
Coal	Short Ton	11	19
Natural Gas	MMBtu	422	813
Oil	Barrels	1	1
Power	MWh	192	185



Foreign Exchange	Dollars	569	279

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, 2022		December 31, 2021		December 31, 2022		December 31, 2021






Derivatives Not Designated as Cash Flow or Fair Value Hedges:
Foreign exchange contracts - current	$	11	$	—	$	1	$	1
Foreign exchange contracts - long-term	7		1		1		—

Commodity contracts- current	7,875		4,613		6,194		3,386
Commodity contracts- long-term	4,101		2,526		2,245		1,412

Total Derivatives Not Designated as Cash Flow or Fair Value Hedges	$	11,994	$	7,140	$	8,441	$	4,799

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, 2022
Foreign exchange contracts:
Derivative assets	$	18	$	(2)	$	—	$	16
Derivative liabilities	(2)		2		—		—
Total foreign exchange contracts	$	16	$	—	$	—	$	16
Commodity contracts:
Derivative assets	$	11,976	$	(7,897)	$	(1,659)	$	2,420
Derivative liabilities	(8,439)		7,897		20		(522)
Total commodity contracts	$	3,537	$	—	$	(1,639)	$	1,898






Total derivative instruments	$	3,553	$	—	$	(1,639)	$	1,914


	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, 2021
Foreign exchange contracts:
Derivative assets	$	1	$	(1)	$	—	$	—
Derivative liabilities	(1)		1		—		—
Total foreign exchange contracts	$	—	$	—	$	—	$	—
Commodity contracts:
Derivative assets	$	7,139	$	(4,440)	$	(831)	$	1,868
Derivative liabilities	(4,798)		4,440		17		(341)
Total commodity contracts	$	2,341	$	—	$	(814)	$	1,527




Total derivative instruments	$	2,341	$	—	$	(814)	$	1,527

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 table summarizes 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.


	Year Ended December 31,
(In millions)	2022		2021		2020
Unrealized mark-to-market results
Reversal of previously recognized unrealized (gains) on settled positions related to economic hedges	$	(1,232)	$	(41)	$	(55)
Reversal of acquired loss positions related to economic hedges	2		256		4
Net unrealized gains/(losses) on open positions related to economic hedges	2,478		2,501		(68)
Total unrealized mark-to-market gains/(losses) for economic hedging activities	1,248		2,716		(119)
Reversal of previously recognized unrealized losses/(gains) on settled positions related to trading activity	13		(18)		(20)
Reversal of acquired (gain) positions related to trading activity	—		(1)		—

Net unrealized (losses)/gains on open positions related to trading activity	(17)		(13)		15
Total unrealized mark-to-market (losses) for trading activity	(4)		(32)		(5)
Total unrealized gains/(losses)	$	1,244	$	2,684	$	(124)


	Year Ended December 31,
(In millions)	2022		2021		2020
Unrealized (losses)/gains included in operating - commodities	$	(87)	$	(196)	$	90
Unrealized gains/(losses) included in cost of operations - commodities	1,315		2,880		(214)
Unrealized gains included in cost of operations - foreign exchange	16		—		—
Total impact to statement of operations	$	1,244	$	2,684	$	(124)

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 $2.5 billion for the years ended December 31, 2022 and 2021 were primarily the result of an increase in value of forward positions as a result of increases in natural gas and power prices.

The loss from open economic hedge positions of $68 million for the year ended December 31, 2020 was primarily the result of a decrease in the value of forward positions as a result of decreases in ERCOT power prices and heat rate contraction, partially offset by an increase in value of forward positions as a result of decreases in New York capacity 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, 2022 was $1.5 billion. The Company is also a party to certain marginable agreements under which it has a net liability position, but the counterparty has not called for the collateral due, which was approximately $195 million as of December 31, 2022. In the event of a downgrade in the Company's credit rating and if called for by the counterparty, $30 million of additional collateral would be required for all contracts with credit rating contingent features as of December 31, 2022.

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

Nuclear Decommissioning Trust Fund

12 Months Ended

Dec. 31, 2022

Regulated Operations [Abstract]

Nuclear Decommissioning Trust Fund

NRG's Nuclear Decommissioning Trust Fund assets, which are for the decommissioning of STP, are comprised of securities classified as available-for-sale and recorded at fair value based on actively quoted market prices. Although NRG is responsible for managing the decommissioning of its 44% interest in STP, the predecessor utilities that owned STP are authorized by the PUCT to collect decommissioning funds from their ratepayers to cover decommissioning costs on behalf of NRG. NRC requirements determine the decommissioning cost estimate, which is the minimum required level of funding. In the event that funds from the ratepayers that accumulate in the nuclear decommissioning trust are ultimately determined to be inadequate to decommission the STP facilities, the utilities will be required to collect through rates charged to rate payers all additional amounts, with no obligation from NRG, provided that NRG has complied with PUCT rules and regulations regarding decommissioning trusts. Following completion of the decommissioning, if surplus funds remain in the decommissioning trusts, any excess will be refunded to the respective ratepayers of the utilities.

NRG accounts for the Nuclear Decommissioning Trust Fund in accordance with ASC 980, Regulated Operations, or ASC 980, because the Company's nuclear decommissioning activities are subject to approval by the PUCT, with regulated rates that are designed to recover all decommissioning costs and that can be charged to and collected from the ratepayers per PUCT mandate. Since the Company is in compliance with PUCT rules and regulations regarding decommissioning trusts and the cost of decommissioning is the responsibility of the Texas ratepayers, not NRG, all realized and unrealized gains or losses (including other-than-temporary impairments) related to the Nuclear Decommissioning Trust Fund are recorded to the Nuclear Decommissioning Trust liability and are not included in net income or accumulated other comprehensive income, consistent with regulatory treatment.

The following table summarizes the aggregate fair values and unrealized gains and losses for the securities held in the trust funds, as well as information about the contractual maturities of those securities.


	As of December 31, 2022							As of December 31, 2021
(In millions, except otherwise noted)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted- average maturities (in years)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted- average maturities (in years)
Cash and cash equivalents	$	15	$	—	$	—	—	$	33	$	—	$	—	—
U.S. government and federal agency obligations	86		—		5		11	112		5		1		10
Federal agency mortgage-backed securities	101		—		11		26	100		2		—		25
Commercial mortgage-backed securities	35		—		4		30	44		1		—		27
Corporate debt securities	114		—		13		12	122		7		1		14
Equity securities	486		346		3		—	593		456		—		—
Foreign government fixed income securities	1		—		—		17	4		—		—		13
Total	$	838	$	346	$	36		$	1,008	$	471	$	2

The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from these sales. The cost of securities sold is determined using the specific identification method.


	Year Ended December 31,
(In millions)	2022		2021		2020
Realized gains	$	14	$	47	$	34
Realized losses	(25)		(9)		(13)
Proceeds from sale of securities	448		710		439

Inventory

12 Months Ended

Dec. 31, 2022

Inventory Disclosure [Abstract]

Inventory

Inventory consisted of:


	As of December 31,
(In millions)	2022		2021
Fuel oil	$	8	$	8
Coal	114		83
Natural gas	385		206
Spare parts and finished goods	244		201
Total Inventory	$	751	$	498

Property, Plant and Equipment

12 Months Ended

Dec. 31, 2022

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

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


	As of December 31,				Depreciable
(In millions)	2022		2021		Lives
Facilities and equipment	$	1,727	$	1,742	1-40 years
Land and improvements	263		271
Nuclear fuel	271		222		5 years
Hardware and office equipment and furnishings	712		637		2-10 years
Construction in progress	197		124
Total property, plant, and equipment	3,170		2,996
Accumulated depreciation	(1,478)		(1,308)
Net property, plant, and equipment	$	1,692	$	1,688

The Company recorded long-lived asset impairments during the years ended December 31, 2022 and 2021, as further described in Note 11, Asset Impairments. Depreciation expense of property, plant and equipment recorded during the years ended December 31, 2022, 2021 and 2020 was $291 million, $384 million and $295 million, respectively.

Leases

12 Months Ended

Dec. 31, 2022

Leases [Abstract]

Leases

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 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)	2022		2021		2020
Finance lease cost	$	4	$	4	$	3


Operating lease cost	85		91		100
Short-term lease cost	7		3		3
Variable lease cost	86		9		6
Sublease income	(2)		(2)		(17)
Total lease cost	$	180	$	105	$	95

Other information:


	For the Year Ended December 31,
(In millions)	2022		2021		2020

Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	183	$	102	$	101

Financing cash flows from finance leases	5		6		1
Right-of-use assets obtained in exchange for new finance lease liabilities	3		16		5
Right-of-use assets obtained in exchange for new operating lease liabilities	28		47		4

Lease Term and Discount Rate for leases:


	December 31, 2022		December 31, 2021
Finance leases:
Weighted average remaining lease term (in years)	2.6		3.6
Weighted average discount rate	2.82	%	2.46	%

Operating leases:
Weighted average remaining lease term (in years)	4.3		4.7
Weighted average discount rate	5.37	%	5.44	%

As of December 31, 2022, annual payments based on the maturities of NRG's operating leases are expected to be as follows:


	In millions
2023	$	97
2024	82
2025	56
2026	14
2027	10
Thereafter	52
Total undiscounted lease payments	$	311
Less: present value adjustment	(48)
Total discounted lease payments	$	263

Asset Impairments	12 Months Ended
Asset Impairments	Dec. 31, 2022
Asset Impairment Charges [Abstract]
Asset Impairments	Asset Impairments 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. 2021 Impairment Losses During the fourth quarter of 2021, 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 the 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. Joliet —The Company recognized an impairment loss of $213 million in the East segment as a result of changes in the long-term outlook of the Joliet facility prompted by market conditions and an assessment of various alternatives for the long-term operational landscape of the facility including the impact of the CEJA in Illinois, which concluded with the annual budget process. Other Impairments — The Company additionally recorded impairment losses of $16 million and $9 million related to various power plants in the East and West/Service/Other segments, respectively. The Company also recorded the following impairment in 2021 based on a specific triggering event that occurred using the same methodology previously discussed: PJM Asset Impairments — During the second quarter of 2021, the results of the PJM Base Residual Auction for the 2022/2023 delivery year were released leading the Company to announce the near-term retirement of a significant portion of its PJM coal generating assets in June 2022. The Company considered the decline in PJM capacity prices and the near-term retirement dates of certain assets to be a trigger for impairment and performed impairment tests on the PJM generating assets and the goodwill associated with Midwest Generation. Impairment losses of $271 million and $35 million were recorded in the East segment on the PJM generating assets and Midwest Generation goodwill, respectively. 2020 Impairment Losses During the fourth quarter of 2020, the Company completed its annual budget and revised its view of long-term power and fuel prices and the corresponding impact on estimated cash flows associated with its long-lives assets. The Cottonwood facility had estimated cash flows that were lower than its carrying amount and the assets were considered impaired. 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 the 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. The Cottonwood facility is being leased through 2025 and the Company recognized an impairment loss of $32 million in 2020 in the West/Services/Other segment associated with the Company's long-term services agreement and related lease payments, as the carrying amounts of the assets from the contract were higher than the estimated operating cash flow though the remaining lease period. The Company also recorded the following impairments in 2020 based on specific triggering events that occurred: Home Solar — In the third quarter of 2020, the Company concluded its Home Solar business was held for sale and recorded an impairment loss of $29 million in the West/Services/Other segment to adjust the carrying amount of the assets and liabilities to fair market value based on indicative sale prices. Petra Nova Parish Holdings — During the first quarter of 2020, due to the decline in oil prices, NRG determined that the carrying amount of the Company’s equity method investment exceeded the fair value of the investment and that the decline is considered to be other-than-temporary. In determining the fair value, the Company utilized an income approach to estimate future project cash flows. The Company recorded $18 million impairment losses on investments in the Texas segment, which included the anticipated drawdown of the $12 million letter of credit posted in September 2019 to cover certain project debt reserve requirements. Other Impairments — For the year ended December 31, 2020, the Company recorded $14 million of impairment losses related to intangible assets in the Texas segment.

Goodwill and Other Intangibles

12 Months Ended

Dec. 31, 2022

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Other Intangibles

Goodwill

The table below presents the changes of goodwill for the years ended December 31, 2022 and 2021 based on the Company's reportable segments.


(in millions)	Texas		East		West/Services/Other		Total
Balance as of January 1, 2021	$	289	$	240	$	50	$	579
Goodwill resulted from the acquisition of Direct Energy	427		648		175		1,250
Impairment losses	—		(35)		—		(35)
Foreign currency translation	—		—		1		1
Balance as of December 31, 2021	$	716	$	853	$	226	$	1,795

Impairment losses	—		(130)		—		(130)
Asset sales	(6)		—		—		(6)
Foreign currency translation	—		—		(9)		(9)
Balance as of December 31, 2022	$	710	$	723	$	217	$	1,650

Intangible Assets

The Company's intangible assets as of December 31, 2022, primarily reflect intangible assets established with the acquisitions of various companies, including Direct Energy, Stream Energy, other retail acquisitions and Texas Genco. Intangible assets are comprised of the following:

•Emission Allowances — These intangibles primarily consist of SO2 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. It also included energy supply contracts acquired with Stream Energy that represent the fair value at the acquisition date of in-market contracts for the purchase of energy to serve retail electric customers and are amortized based on the expected delivery under the respective contracts.

•Customer relationships — These intangibles represent the fair value at the acquisition date of acquired businesses' customer base from the acquisition of Direct Energy and other acquisitions. The 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. The marketing partnerships are amortized to depreciation and amortization expense 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 credits. RECs are retired, as required, for the applicable compliance period. They are expensed to cost of operations based on NRG’s customer usage. It also includes in-market nuclear fuel contracts established from the Texas Genco acquisition in 2006 which are 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 are amortized to depreciation and amortization expense.

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


(In millions)
Year Ended December 31, 2022	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Trade Names		Other(b)		Total
January 1, 2022	$	634	$	638	$	1,679	$	284	$	683	$	229	$	4,147
Purchases	26		—		—		—		—		404		430
Acquisition of businesses (a)	—		—		55		—		—		—		55
Usage/Sales/Retirements	(33)		—		—		—		—		(341)		(374)
Write-off of fully amortized balances	(14)		—		—		—		—		—		(14)

Other	11		(3)		(4)		—		(4)		—		—
December 31, 2022	624		635		1,730		284		679		292		4,244
Less accumulated amortization	(528)		(235)		(787)		(146)		(341)		(75)		(2,112)
Net carrying amount	$	96	$	400	$	943	$	138	$	338	$	217	$	2,132

(a)The weighted average life of acquired amortizable intangibles was six years for customer relationships

(b)RECs are not subject to amortization and had a carrying value of $186 million


(In millions)
Year Ended December 31, 2021	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Trade Names		Other(b)		Total
January 1, 2021	$	672	$	28	$	527	$	285	$	373	$	140	$	2,025
Purchases	10		—		—		—		—		338		348
Acquisition of businesses (a)	—		610		1,308		—		310		124		2,352
Usage/Retirements	(1)		—		—		—		—		(364)		(365)
Write-off of fully amortized balances	(51)		—		(158)		—		—		(7)		(216)

Other	4		—		2		(1)		—		(2)		3
December 31, 2021	634		638		1,679		284		683		229		4,147
Less accumulated amortization	(536)		(94)		(518)		(123)		(294)		(71)		(1,636)
Net carrying amount	$	98	$	544	$	1,161	$	161	$	389	$	158	$	2,511

(a)The weighted average life of total acquired amortizable intangibles from the Direct Energy acquisition was 12 years

(b)RECs are not subject to amortization and had a carrying value of $123 million

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


	Years Ended December 31,
(In millions)	2022		2021		2020
Emission allowances	$	6	$	24	$	28
Customer and supply contracts	141		66		12
Customer relationships	269		327		74
Marketing partnerships	23		24		24
Trade names	47		47		27
Other(a)	4		7		3
Total amortization	$	490	$	495	$	168

(a)For the years ended December 31, 2022, 2021 and 2020, other intangibles were amortized to depreciation and amortization expense for $4 million, $3 million and $3 million, respectively

The following table presents estimated amortization of NRG's intangible assets as of December 31, 2022 for each of the next five years:


(In millions)
Year Ended December 31,	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Trade Names		Other		Total
2023	$	18	$	119	$	226	$	23	$	46	$	4	$	436
2024	19		73		159		23		38		3		315
2025	18		50		118		22		31		4		243
2026	10		52		103		22		23		3		213
2027	10		30		74		22		23		3		162

Intangible assets held-for-sale — From time to time, management may authorize the transfer from the Company's emission bank of emission allowances held-for-use to intangible assets held-for-sale. Emission allowances held-for-sale are included in other non-current assets on the Company's consolidated balance sheet and are not amortized, but rather expensed as sold. As of December 31, 2022 and 2021, the value of emission allowances held-for-sale was $8 million and $15 million, respectively, within the Corporate segment. Once transferred to held-for-sale, these emission allowances are prohibited from moving back to held-for-use.

Asset Retirement Obligations

12 Months Ended

Dec. 31, 2022

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

The Company's AROs are primarily related to the environmental obligations for nuclear decommissioning, 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.

See Note 7, Nuclear Decommissioning Trust Fund, for a further discussion of the Company's nuclear decommissioning obligations. Accretion for the nuclear decommissioning ARO and amortization of the related ARO asset are recorded to the Nuclear Decommissioning Trust Liability to the ratepayers and are not included in net income, consistent with treatment per ASC 980, Regulated Operations.

The following table represents the balance of ARO obligations as of December 31, 2022 and 2021, along with the additions, reductions and accretion related to the Company's ARO obligations for the year ended December 31, 2022:


(In millions)	Nuclear Decommission		Other(a)		Total
Balance as of December 31, 2021	$	321	$	399	$	720
Revisions in estimates for current obligations	—		38		38
Additions	—		1		1
Spending for current obligations	—		(33)		(33)
Accretion	19		19		38
Other	—		(6)		(6)
Balance as of December 31, 2022	$	340	$	418	$	758

(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

Long-term Debt and Finance Leases

12 Months Ended

Dec. 31, 2022

Debt Disclosure [Abstract]

Long-term Debt and Finance Leases

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


(In millions, except rates)	December 31, 2022		December 31, 2021		Interest rate %

Recourse debt:
Senior Notes, due 2027	$	375	$	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 2031	1,030		1,030		3.625
Senior Notes, due 2032	1,100		1,100		3.875
Convertible Senior Notes, due 2048(a)	575		575		2.750
Senior Secured First Lien Notes, due 2024	600		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

Tax-exempt bonds	466		466		1.250 - 4.750




Subtotal long-term debt (including current maturities)	8,100		8,100
Finance leases	11		13		various

Subtotal long-term debt and finance leases (including current maturities)	8,111		8,113
Less current maturities	(63)		(4)
Less debt issuance costs	(70)		(83)
Discounts	(2)		(60)
Total long-term debt and finance leases	$	7,976	$	7,966

(a)As of the ex-dividend date of January 31, 2023, the Convertible Senior Notes were convertible at a price of $43.01, which is equivalent to a conversion rate of approximately 23.2527 shares of common stock per $1,000 principal amount.

Debt includes the following discounts:


	As of December 31,
(In millions)	2022		2021
Senior Secured First Lien Notes, due 2024, 2025, 2027 and 2029	$	(2)	$	(2)
Convertible Senior Notes, due 2048	—		(58)
Total discounts	$	(2)	$	(60)

Consolidated Annual Maturities

As of December 31, 2022, annual payments based on the maturities of NRG's debt and finance leases are expected to be as follows:


	(In millions)
2023	$	63
2024	604
2025	749
2026	1
2027	1,275
Thereafter	5,419
Total	$	8,111

Revolving Credit Facility

On February 14, 2023 (the “Revolving Credit Facility Amendment Effective Date”), the Company amended its Revolving Credit Facility to: (i) increase the existing revolving commitments thereunder by $600 million (the “Incremental Commitment”), (ii) extend the maturity date of a portion of the revolving commitments thereunder to February 14, 2028, (iii) transition the benchmark rate applicable to revolving loans from LIBOR to SOFR and (iv) make certain other amendments to the terms of the Revolving Credit Facility for purposes of, among other things, providing additional flexibility.

After giving effect to the Incremental Commitment on the Revolving Credit Facility Amendment Effective Date, the Company will have a total of $4.275 billion of revolving commitments under the Revolving Credit Facility. The full amount of the Incremental Commitment was made available from and after the Revolving Credit Facility Amendment Effective Date but will be reduced by $500 million if the Vivint acquisition is not consummated. A portion of the non-extended revolving commitments will terminate on July 5, 2023, with the remaining portion terminating on May 28, 2024, in each case, unless otherwise extended.

The Revolving Credit Facility is guaranteed by NRG’s existing and future direct and indirect subsidiaries, with customary and agreed-upon exceptions, for, among other exceptions, unrestricted subsidiaries, foreign subsidiaries, project subsidiaries, immaterial subsidiaries, captive insurance subsidiaries and securitization vehicles. The Revolving Credit Facility is also secured by a first priority perfected security interest in a substantial portion of the property and assets owned by NRG and its subsidiaries that are guarantors under the Revolving Credit Facility, subject to certain exceptions that include, among other things, the capital stock of certain specified subsidiaries, including unrestricted subsidiaries and certain excluded subsidiaries, equity interests in excess of 66% of the total outstanding voting equity interests of certain foreign subsidiaries, equity interests the pledge of which is prohibited by applicable agreements binding on such subsidiaries and other assets that may be designated by NRG as excluded from the collateral that, when taken together with all other assets so designated since the Revolving Credit Facility Amendment Effective Date, have an aggregate fair market value not exceeding $750 million. The Revolving Credit Facility is secured on a pari passu basis with certain interest rate, foreign currency and commodity hedging obligations of NRG, the Senior Secured Notes and certain other indebtedness.

The Revolving Credit Facility contains customary covenants, which, among other things, require NRG to maintain a minimum interest coverage ratio and a maximum first lien leverage ratio on a consolidated basis and limit NRG’s ability to:

•incur indebtedness and liens and enter into sale and lease-back transactions;

•make investments, loans and advances;

•return capital to shareholders;

•repay subordinated indebtedness;

•consummate mergers, consolidations and asset sales;

•enter into affiliate transactions; and

•change its fiscal year-end.

As of December 31, 2022, there were no outstanding borrowings and there were $1.6 billion in letters of credit issued under the Revolving Credit Facility.

Senior Notes

Issuance of 2032 Senior Notes

On August 23, 2021, the Company issued $1.1 billion of aggregate principal amount of 3.875% senior notes due 2032. The 2032 Senior Notes are senior unsecured obligations of NRG and are guaranteed by certain of its subsidiaries. Interest is paid semi-annually beginning on February 15, 2022 until the maturity date of February 15, 2032. The 2032 Senior Notes were issued under NRG's Sustainability-Linked Bond Framework, which sets out certain sustainability targets, including reducing greenhouse gas emissions. Failure to meet such sustainability targets will result in a 25 basis point increase to the interest rate payable on the 2032 Senior Notes from and including August 15, 2026. The proceeds of the 2032 Senior Notes, along with cash on hand, were used to fund the redemption of $1.0 billion aggregate principal amount of the 7.250% Senior Notes due 2026 and $355 million aggregate principal amounts of the 6.625% Senior Notes due 2027.

Senior Note Redemptions

During the year ended December 31, 2021, the Company redeemed approximately $1.9 billion in aggregate principal amount of its Senior Notes for $1.9 billion using the proceeds of the 2032 Senior Notes and cash on hand, as detailed in the table below. In connection with the redemptions, a $77 million loss on debt extinguishment was recorded, which included the write-off of previously deferred financing costs of $12 million.


(In millions, except percentages)	Principal Repurchased		Cash Paid(a)		Average Early Redemption Percentage
7.250% Senior Notes, due 2026	$	1,000	$	1,056	103.625	%
6.625% Senior Notes, due 2027	855		893		103.313	%
Total	$	1,855	$	1,949

(a) Includes accrued interest of $29 million for redemptions for the year ended December 31, 2021

2048 Convertible Senior Notes

Accounting for Convertible Senior Notes — Upon issuance in 2018, the Convertible Senior Notes were separated into liability and equity components for accounting purposes. The carrying amount of the liability component was initially calculated by measuring the fair value of similar liabilities that do not have an associated convertible feature. The carrying amount of the equity component representing the conversion option was determined by deducting the fair value of the liability component from the par value of the Convertible Senior Notes. This difference represented the debt discount that was amortized to interest expense over seven years, which was determined to be the expected life of the Convertible Senior Notes, using the effective interest rate method. The equity component was recorded in additional paid-in capital and was not remeasured as it continued to meet the conditions for equity classification.

Following the adoption of ASU 2020-06 as of January 1, 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. As a result of the provisions of the amended guidance, the Company recorded a $100 million decrease to additional paid-in capital, a $57 million decrease to debt discount, a $57 million increase to retained earnings, and a $14 million decrease to long-term deferred tax liabilities. For more information on the adoption of ASU 2020-06, refer to Note 2, Summary of Significant Accounting Policies.

Modification to Convertible Senior Notes — On February 22, 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.

Convertible Senior Notes Features — As of December 31, 2022, the Convertible Senior Notes were convertible, under certain circumstances, into cash or a combination of cash and the Company’s common stock at a price of $43.46 per common share, which is equivalent to a conversion rate of approximately 23.0116 shares of common stock per $1,000 principal amount of Convertible Senior Notes. As of December 31, 2021, the Convertible Senior Notes were convertible at a price of $44.89 per common share, which is equivalent to a conversion rate of approximately 22.2761 shares of common stock per $1,000 principal amount of Convertible Senior Notes. The net carrying amounts of the Convertible Senior Notes as of December 31, 2022 and December 31, 2021 were $570 million and $512 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 under certain circumstances. Prior to the close of business on the business day immediately preceding December 1, 2024, the Convertible Senior Notes will be convertible only upon the occurrence of certain events and during certain periods, and thereafter 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

The following table details the interest expense recorded in connection with the Convertible Senior Notes, due 2048:


	For the years ended December 31,
($ In millions)	2022			2021			2020
Contractual interest expense	$	16		$	16		$	16
Amortization of discount and deferred finance costs(a)	1			15			14
Total	$	17		$	31		$	30

Effective Interest Rate	3.01		%	5.34		%	5.19		%

(a)Upon adoption of ASU 2020-06 on January 1, 2022, which resulted in the removal of the debt discount, no further debt discount amortization is being recorded

Senior Notes Early Redemption

As of December 31, 2022, NRG had the following outstanding issuances of senior notes with an early redemption feature, or Senior Notes:

i.6.625% senior notes, issued August 2, 2016 and due January 15, 2027, or the 2027 Senior Notes;

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

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

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

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

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

The Company periodically enters into supplemental indentures for the purpose of adding entities under the Senior Notes as guarantors.

The indentures and the forms of notes provide, among other things, that the Senior Notes will be senior unsecured obligations of NRG. The indentures also provide for customary events of default, which include, among others: nonpayment of principal or interest; breach of other agreements in the indentures; defaults in failure to pay certain other indebtedness; the rendering of judgments to pay certain amounts of money against NRG and its subsidiaries; the failure of certain guarantees to be enforceable; and certain events of bankruptcy or insolvency. Generally, if an event of default occurs, 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, among other things, limit NRG's ability and certain of its subsidiaries' ability to return capital to stockholders, grant liens on assets to lenders and incur additional debt. Interest is payable semi-annually on the Senior Notes until their maturity dates.

2027 Senior Notes

NRG may redeem some or all of the 2027 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 to the first applicable redemption date:


Redemption Period	Redemption Percentage
July 15, 2022 to July 14, 2023	102.208	%
July 15, 2023 to July 14, 2024	101.104	%
July 15, 2024 and thereafter	100.000	%

2028 Senior Notes

NRG 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 to the first applicable redemption date:


Redemption Period	Redemption Percentage
January 15, 2023 to January 14, 2024	102.875	%
January 15, 2024 to January 14, 2025	101.917	%
January 15, 2025 to January 14, 2026	100.958	%
January 15, 2026 and thereafter	100.000	%

5.250% 2029 Senior Notes

At any time prior to June 15, 2024, NRG may redeem all or a part of the 2029 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 the principal amount of the note over the following: the present value of 102.625% of the note, plus interest payments due on the note through June 15, 2024 (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%. In addition, on or after June 15, 2024, NRG 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 to the first applicable 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	%

3.375% 2029 Senior Notes

At any time prior to February 15, 2024, NRG may redeem up to 40% of the aggregate principal amount of the 2029 Senior Notes, at a redemption price equal to 103.375% of the principal amount of the notes redeemed, plus accrued and unpaid interest, with an amount equal to the net cash proceeds of certain equity offerings, provided that at least 50% of the aggregate principal amount remains outstanding immediately after the occurrence of such redemption. At any time prior to February 15, 2024, NRG may redeem all or a part of the 2029 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 the principal amount of the note over the following: the present value of 101.688% of the note, plus interest payments due on the note through February 15, 2024 (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%. In addition, on or after February 15, 2024, NRG 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 to the first applicable redemption date:


Redemption Period	Redemption Percentage
February 15, 2024 to February 14, 2025	101.688	%
February 15, 2025 to February 14, 2026	100.844	%
February 15, 2026 and thereafter	100.000	%

2031 Senior Notes

At any time prior to February 15, 2026, NRG may redeem up to 40% of the aggregate principal amount of the 2031 Senior Notes, at a redemption price equal to 103.625% of the principal amount of the notes redeemed, plus accrued and unpaid interest, with an amount equal to the net cash proceeds of certain equity offerings, provided that at least 50% of the aggregate principal amount remains outstanding immediately after the occurrence of such redemption. At any time prior to February 15, 2026, NRG 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 notes; or (ii) the excess of the principal amount of the note over the following: 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%. In addition, on or after February 15, 2026, NRG 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 to the first applicable 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	%

2032 Senior Notes

At any time prior to August 15, 2024, NRG may redeem up to 40% of the aggregate principal amount of the 2032 Senior Notes, at a redemption price equal to 103.875% of the principal amount of the notes redeemed, plus accrued and unpaid interest, with an amount equal to the net cash proceeds of certain equity offerings, provided that at least 50% of the aggregate principal amount remains outstanding immediately after the occurrence of such redemption. At any time prior to February 15, 2027, NRG 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, NRG 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 to the first applicable 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	%

Receivables Facility

In 2020, NRG Receivables LLC, a bankruptcy remote, special purpose, indirect wholly owned subsidiary, entered into the Receivables Facility for an amount up to $750 million, subject to adjustments on a seasonal basis, with issuers of asset-backed commercial paper and commercial banks (the "Lenders".) The assets of NRG Receivables LLC are first available to satisfy the claims of the Lenders before making payments on the subordinated note and equity issued by NRG Receivables LLC. The assets of NRG Receivables LLC are not available to the Company and its subsidiaries or creditors unless and until distributed by NRG Receivables LLC. Under the Receivables Facility, certain indirect subsidiaries of the Company sell their accounts receivables to NRG Receivables LLC, subject to certain terms and conditions. In turn, NRG Receivables LLC 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 LLC 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 will continue to service the accounts receivables sold in exchange for a servicing fee.

On July 26, 2022, NRG Receivables LLC, a wholly-owned indirect subsidiary of the Company, entered into an amendment to its Receivables Facility dated September 22, 2020 with a group of conduit lenders and banks and Royal Bank of Canada, as Administrative Agent to, among other things, (i) extend the scheduled termination date by one year, (ii) increase the aggregate commitments from $800 million to $1.0 billion, (iii) increase the letter of credit sublimit to equal the aggregate commitments, (iv) replace LIBOR with Term SOFR as the benchmark for borrowings and (v) add new originators. Borrowings by NRG Receivables LLC under the Receivables Facility bear interest as defined under the Receivables Financing Agreement. The weighted average interest rate related to usage under the Receivables Facility as of December 31, 2022 was 0.844%. As of December 31, 2022, there were no outstanding borrowings and there were $721 million in letters of credit issued under the Receivables Facility.

Repurchase Facility

In 2020, the Company entered into the Repurchase Facility related to the Receivables Facility. Under the Repurchase Facility, the Company can borrow up to $75 million, collateralized by a subordinated note issued by NRG Receivables LLC to NRG Retail LLC in favor of the originating entities representing a portion of the balance of receivables sold to NRG Receivables LLC under the Receivables Facility.

On February 9, 2022, the Company entered into amendments to its existing Repurchase Facility to, among other things, (i) increase the size of the facility from $75 million to $150 million and (ii) replace LIBOR with term SOFR as the benchmark for the pricing rate. On July 26, 2022, the Company renewed its existing Repurchase Facility to, among other things, extend the maturity date to July 26, 2023. The Repurchase Facility has no commitment fee and borrowings will be drawn at SOFR + 1.30%. As of December 31, 2022, there were no outstanding borrowings under the Repurchase Facility.

Bilateral Letter of Credit Facilities

On April 29, 2022, May 27, 2022 and October 13, 2022, the Company increased the size of the facilities by $100 million, $50 million and $50 million respectively, to provide additional liquidity, allowing for the issuance of up to $675 million of letters of credit. These facilities are uncommitted. As of December 31, 2022, $668 million was issued under these facilities.

Tax Exempt Bonds


	As of December 31,
(In millions, except rates)	2022		2021		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		1.300
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

- Definition

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

+ References

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-URI https://asc.fasb.org/topic&trid=2208564

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1B
-Subparagraph (h)
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495323-112611

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1C
-Subparagraph (c)
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495334-112611

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1I
-Subparagraph (a)
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495371-112611

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1I
-Subparagraph (d)
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495371-112611

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(c))
-URI https://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1B
-Subparagraph (g)
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495323-112611

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1C
-Subparagraph (b)
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495334-112611

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1C
-Subparagraph (a)
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495334-112611

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1E
-Subparagraph (b)
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495348-112611

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1B
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495323-112611

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1I
-Subparagraph (b)
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495371-112611

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1B
-Subparagraph (i)
-URI https://asc.fasb.org/extlink&oid=123466505&loc=SL123495323-112611

+ Details

Benefit Plans and Other Postretirement Benefits

12 Months Ended

Dec. 31, 2022

Retirement Benefits [Abstract]

Benefit Plans and Other Postretirement Benefits

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. The Pension Plan for Employees of DEML is closed to new participants.

NRG expects to contribute $83 million to the Company's pension plans in 2023, of which $45 million relates to the GenOn plan.

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)	2022		2021		2020
Service cost benefits earned	$	7	$	9	$	10
Interest cost on benefit obligation	41		27		38
Expected return on plan assets	(47)		(66)		(61)
Amortization of unrecognized net loss	3		1		5
Settlement/curtailment expense	14		2		—
Net periodic benefit cost/(credit)	$	18	$	(27)	$	(8)


	Year Ended December 31,
	Other Postretirement Benefits
(In millions)	2022		2021		2020

Interest cost on benefit obligation	$	2	$	2	$	3
Amortization of unrecognized prior service cost	(8)		(10)		(14)
Amortization of unrecognized net loss	2		1		1
Curtailment loss	—		1		—
Net periodic benefit credit	$	(4)	$	(6)	$	(10)

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)	2022		2021		2022		2021
Benefit obligation at January 1	$	1,452	$	1,489	$	105	$	90
Acquired benefit obligation from Direct Energy	—		74		—		19
Service cost	7		9		—		—
Interest cost	41		27		2		2

Actuarial gain	(289)		(55)		(11)		—
Employee and retiree contributions	—		—		3		3
Curtailment loss	—		—		—		1
Benefit payments	(171)		(93)		(15)		(10)
Foreign exchange translation	(4)		1		—		—
Benefit obligation at December 31	1,036		1,452		84		105
Fair value of plan assets at January 1	1,336		1,272		—		—
Acquired fair value of plan assets from Direct Energy	—		64		—		—
Actual return on plan assets	(317)		85		—		—
Employee and retiree contributions	—		—		3		3
Employer contributions	—		7		12		7
Benefit payments	(171)		(93)		(15)		(10)
Foreign exchange translation	(4)		1		—		—
Fair value of plan assets at December 31	844		1,336		—		—
Funded status at December 31 — excess of obligation over assets	$	(192)	$	(116)	$	(84)	$	(105)

During the year ended December 31, 2022, the actuarial gain of $289 million on pension benefits was primarily driven by increasing discount rates.

During the year ended December 31, 2021, the actuarial gain of $55 million on pension benefits was primarily driven by increasing discount rates and changes in demographic assumptions.

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


	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2022		2021		2022		2021
Other current liabilities	$	—	$	—	$	7	$	7
Other non-current liabilities	192		116		77		98

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)	2022		2021		2022		2021
Net loss/(gain)	$	110	$	52	$	(7)	$	5
Prior service cost/(credit)	1		2		(12)		(19)
Total accumulated OCI	$	111	$	54	$	(19)	$	(14)

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)	2022		2021		2022		2021
Net actuarial loss/(gain)	$	74	$	(72)	$	(11)	$	—
Amortization of net actuarial loss	(3)		(1)		(2)		(1)


Amortization of prior service cost	—		—		8		10
Effect of settlement/curtailment	(14)		(2)		—		—
Total recognized in OCI	$	57	$	(75)	$	(5)	$	9
Net periodic benefit cost/(credit)	18		(27)		(4)		(6)
Net recognized in net periodic pension cost/(credit) and OCI	$	75	$	(102)	$	(9)	$	3

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


	As of December 31,
	Pension Benefits
(In millions)	2022		2021
Projected benefit obligation	$	1,036	$	1,452
Accumulated benefit obligation	1,022		1,423
Fair value of plan assets	844		1,336

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, 2022
(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	$	—	$	155	$	155
Common/collective trust investment — non-U.S. equity	—		65		65
Common/collective trust investment — non-core assets	—		90		90
Common/collective trust investment — fixed income	—		181		181
Short-term investment fund	22		—		22
Subtotal fair value	$	22	$	491	$	513
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity					33
Common/collective trust investment — fixed income					220
Common/collective trust investment — non-core assets					55
Partnerships/joint ventures					23
Total fair value					$	844


	Fair Value Measurements as of December 31, 2021
(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	$	—	$	221	$	221
Common/collective trust investment — non-U.S. equity	—		69		69
Common/collective trust investment — non-core assets	—		110		110
Common/collective trust investment — fixed income	—		340		340
Short-term investment fund	13		—		13
Subtotal fair value	$	13	$	740	$	753
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity					78
Common/collective trust investment — fixed income					405
Common/collective trust investment — non-core assets					65
Partnerships/joint ventures					35
Total fair value					$	1,336

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	2022		2021		2022		2021
Discount rate	5.18	%	2.89	%	5.19	%	2.89	%
Interest crediting rate	5.21	%	3.07	%	4.00	%	1.94	%
Rate of compensation increase	3.06	%	3.06	%	—	%	—	%
Health care trend rate	—		—		7.0% grading to 4.4% in 2031		6.8% grading to 4.4% in 2028

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	2022		2021		2020		2022		2021		2020
Discount rate	2.89%/4.71%/5.41%		2.55	%	3.26	%	2.82	%	2.81	%	3.26	%
Interest crediting rate	3.07	%	3.13	%	3.66	%	1.94	%	1.62	%	2.28	%
Expected return on plan assets	4.99	%	5.62	%	5.93	%	—		—		—
Rate of compensation increase	3.06	%	3.06	%	3.00	%	—		—		—
Health care trend rate	—		—		—		6.9% grading to 4.4% in 2028		7.0% grading to 4.4% in 2028		7.5% grading to 4.5% in 2028

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, 2022:


U.S. equity	21	%
Non-U.S. equity	14	%
Non-core assets	18	%
Fixed Income	47	%

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.

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
2023	$	83	$	7	$	—
2024	81		7		—
2025	79		6		—
2026	77		6		—
2027	76		6		—
2028-2032	361		27		2

STP Defined Benefit Plans

NRG has a 44% undivided ownership interest in STP, as discussed further in Note 28, Jointly Owned Plants. STPNOC, which operates and maintains STP, provides its employees a defined benefit pension plan, as well as postretirement health and welfare benefits. Although NRG does not sponsor the STP plan, it reimburses STPNOC for 44% of the contributions made towards its retirement plan obligations. The STPNOC defined benefit pension plan was frozen to all employees during 2021.

For the years ended December 31, 2022 and December 31, 2021, NRG reimbursed STPNOC $18 million and $17 million, respectively, for its contribution to the plans. In 2023, NRG expects to reimburse STPNOC $10 million for its contribution to the plan.

The Company has recognized the following in its statement of financial position, statement of operations and accumulated OCI related to its 44% interest in STP:


	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2022		2021		2022		2021
Funded status — STPNOC benefit plans	$	(7)	$	(50)	$	(13)	$	(18)
Net periodic benefit cost/(credit)	2		17		(4)		(4)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	(27)		(51)		1		4

Defined Contribution Plans

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

The Company's contributions to these plans were as follows:


	Year Ended December 31,
(In millions)	2022		2021		2020
Company contributions to defined contribution plans	$	26	$	25	$	22

- Definition

The entire disclosure for retirement benefits.

+ References

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+ Details

Capital Structure

12 Months Ended

Dec. 31, 2022

Equity [Abstract]

Capital Structure

For the period from December 31, 2019 to December 31, 2022, 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 common shares issued and outstanding for each period presented:


	Common Shares
	Issued	Treasury	Outstanding
Balance as of December 31, 2019	421,890,790	(172,894,601)	248,996,189
Shares issued under ESPP	—	131,469	131,469
Shares issued under LTIPs	1,167,058	—	1,167,058
Share repurchases	—	(6,062,783)	(6,062,783)
Balance as of December 31, 2020	423,057,848	(178,825,915)	244,231,933
Shares issued under ESPP	—	117,392	117,392
Shares issued under LTIPs	489,326	—	489,326
Share repurchases	—	(1,084,752)	(1,084,752)
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
Shares issued under LTIPs	213,208	—	213,208

Balance as of February 15, 2023	424,110,209	(194,335,971)	229,774,238

Common Stock

As of December 31, 2022, NRG had 14,022,916 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 $0.350, $0.325 and $0.30 quarterly dividend per common share, or $1.40, $1.30 and $1.20 per share on an annualized basis for 2022, 2021 and 2020 respectively.

In the first quarter of 2020, NRG increased the annual dividend to $1.20 from $0.12 per share, as part of a long-term capital allocation policy adopted in the fourth quarter of 2019. In 2021, 2022 and 2023, NRG increased the annual dividend to $1.30, $1.40 and $1.51 per share, respectively, representing an 8% increase each year. The long-term capital allocation policy targets an annual 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 20, 2023, NRG declared a quarterly dividend on the Company's common stock of $0.3775 per share, or $1.51 per share on an annualized basis, payable on February 15, 2023, to stockholders of record as of February 1, 2023.

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 95% of its market value on the offering date or 95% of the fair market value on the exercise date. An offering date will occur each April 1 and October 1. An exercise date will occur each September 30 and March 31. As of December 31, 2021, there remained 2,493,374 shares of treasury stock reserved for issuance under the ESPP.

Share Repurchases

In December 2021, the Company announced that the Board of Directors authorized $1 billion for share repurchases as part of NRG’s Capital Allocation policy. The program began with $44 million of repurchases in December 2021, and an incremental $601 million was repurchased in 2022. The balance of $355 million under the current program is expected to be repurchased in 2023, subject to the availability of excess cash and full visibility of the achievement of the Company's 2023 targeted credit metrics.

In October 2022, the Company announced its 2023 capital allocation plan which, consistent with NRG's stated strategy of returning 50% of cash available for allocation to shareholders, included $600 million incremental share repurchases to be completed in 2023. In connection with the anticipated Vivint acquisition, the Company updated its 2023 capital allocation plan by reallocating 2023 capital primarily to fund the Vivint acquisition, dividend payments and debt reduction. Following the completion of the Vivint acquisition, the Company plans to further update its 2023 capital allocation plan.

The following table summarizes the shares repurchases made during the years ended December 31, 2020, 2021 and 2022:


	Total number of shares and share equivalents purchased	Average price paid per share and share equivalent		Amounts paid for shares and share equivalents purchased (in millions)


2020 repurchases:
Repurchases	6,062,783			197

Equivalent shares purchased in lieu of tax withholdings on equity compensation issuances(a)	711,248			27
Total Share Repurchases during 2020	6,774,031	$	33.05	$	224
2021 repurchases:
Repurchases(b)	1,084,752			44
Equivalent shares purchased in lieu of tax withholdings on equity compensation issuances(a)	249,013			9
Total Share Repurchases during 2021	1,333,765	$	40.22	$	53
2022 repurchases:
Repurchases	14,685,521			595
Equivalent shares purchased in lieu of tax withholdings on equity compensation issuances(a)	151,241			6
Total Share Repurchases during 2022	14,836,762	$	40.50	$	601

(a)NRG elected to pay cash for tax withholding on equity awards instead of issuing actual shares to management. The average price per equivalent shares withheld was $42.74, $37.50 and $38.23 in 2022, 2021 and 2020, respectively. See Note 21, Stock-Based Compensation, for further discussion of the equity awards

(b)Includes $5 million accrued as of December 31, 2021

- Definition

The entire disclosure for shareholders' equity comprised of portions attributable to the parent entity and noncontrolling interest, including other comprehensive income. Includes, but is not limited to, balances of common stock, preferred stock, additional paid-in capital, other capital and retained earnings, accumulated balance for each classification of other comprehensive income and amount of comprehensive income.

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+ Details

Investments Accounted for by the Equity Method and Variable Interest Entities

12 Months Ended

Dec. 31, 2022

Equity Method Investments and Joint Ventures [Abstract]

Investments Accounted for by the Equity Method and Variable Interest Entities

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, unrealized gains and losses on derivatives and movements in foreign currency exchange rates.

On June 1, 2022, the Company sold its 49% ownership in the Watson natural gas generating facility for $59 million as further described in Note 4, Acquisitions and Dispositions. On September 14, 2022, the Company sold its 50% ownership in Petra Nova natural gas generating facility. The following table summarizes NRG's equity method investments as of December 31, 2022:


(In millions, except percentages)
Name:	Economic Interest		Investment Balance
Gladstone	37.5	%	$	128
Ivanpah Master Holdings, LLC(a)	54.5	%	—
Midway-Sunset Cogeneration Company	50.0	%	5
Total equity investments in affiliates			$	133

(a) The equity method of accounting for Ivanpah has been suspended based on losses generated by the project, including the impact of debt service and depreciation

The following table summarizes the undistributed earnings from NRG's equity method investments as of December 31, 2022:


	As of December 31,
(In millions)	2022		2021
Undistributed earnings	$	42	$	33

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 $128 million as of December 31, 2022.

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 13, Long-term Debt and Finance Leases.

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


(In millions)	December 31, 2022		December 31, 2021
Accounts receivable and Other current assets	$	2,108	$	939




Current liabilities	152		78




Net assets	$	1,956	$	861

Income Per Share

12 Months Ended

Dec. 31, 2022

Earnings Per Share [Abstract]

Income Per Share

Basic income per common share is computed by dividing net income 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 per share is computed in a manner consistent with that of basic income per share, while giving effect to all potentially dilutive common shares that were outstanding during the period.

Dilutive effect for equity compensation and other equity instruments — The relative performance stock units, non-vested restricted stock units, market stock units and non-qualified stock options are not considered outstanding for purposes of computing basic income per share. However, these instruments are included in the denominator for purposes of computing diluted income 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. Prior to adoption of ASU 2020-06, there was no dilutive effect for the Convertible Senior Notes due to the Company’s expectation to settle the liability in cash. Upon adoption of ASU 2020-06, on January 1, 2022, the Company is including the potential share settlements, if any, in the denominator for purposes of computing diluted income 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. For the year ended December 31, 2022, there was no dilutive effect for the Convertible Senior Notes since there were no potential share settlements for the period.

The reconciliation of NRG's basic income per share to diluted income per share is shown in the following table:


	Year Ended December 31,
(In millions, except per share amounts)	2022		2021		2020
Basic income per share attributable to NRG Energy, Inc;
Net income attributable to NRG Energy, Inc. common stockholders	$	1,221	$	2,187	$	510



Weighted average number of common shares outstanding-basic	236		245		245
Income per weighted average common share — basic	$	5.17	$	8.93	$	2.08
Diluted income per share attributable to NRG Energy, Inc;
Net income attributable to NRG Energy, Inc. common stockholders	$	1,221	$	2,187	$	510
Weighted average number of common shares outstanding-basic	236		245		245
Incremental shares attributable to the issuance of equity compensation (treasury stock method)	—		—		1
Weighted average number of common shares outstanding-diluted	236		245		246
Income per weighted average common share — diluted	$	5.17	$	8.93	$	2.07

As of December 31, 2022, 2021 and 2020, the Company had an insignificant number of outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company’s diluted income per share.

Segment Reporting

12 Months Ended

Dec. 31, 2022

Segment Reporting [Abstract]

Segment Reporting

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 and wholesale generation businesses with a geographical focus.

NRG's chief operating decision maker, its chief executive officer, evaluates the performance of its segments based on operational measures including adjusted earnings before interest, taxes, depreciation and amortization, or Adjusted EBITDA, free cash flow and allocation of capital, as well as net income/(loss).

The Company had no customer that comprised more than 10% of the Company's consolidated revenues during the years ended December 31, 2022, 2021 and 2020.

Intersegment sales are accounted for at market.


	For the Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenues(a)	$	10,057	$	16,763	$	4,706	$	—	$	17	$	31,543
Operating expenses	8,495		16,031		4,108		86		17		28,737
Depreciation and amortization	310		208		85		31		—		634
Impairment losses	—		206		—		—		—		206
Total operating cost and expenses	8,805		16,445		4,193		117		17		29,577

Gain 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	5		10		3		54		(16)		56

Interest expense	—		(1)		(32)		(400)		16		(417)
Income/(loss) before income taxes	1,265		327		537		(466)		—		1,663
Income tax expense	—		1		57		384		—		442




Net income/(loss)	$	1,265	$	326	$	480	$	(850)	$	—	$	1,221

Balance sheet
Equity investments in affiliates	$	—	$	—	$	133	$	—	$	—	$	133
Capital expenditures	273		7		37		50		—		367
Goodwill	710		723		217		—		—		1,650
Total assets	$	11,475	$	19,526	$	8,139	$	35,780	$	(45,774)	$	29,146


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


	For the Year Ended December 31, 2021
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenues(a)	$	10,295	$	13,025	$	3,659	$	—	$	10	$	26,989
Operating expenses	8,692		10,256		3,467		141		10		22,566
Depreciation and amortization	336		333		88		28		—		785
Impairment losses	—		535		9		—		—		544
Total operating cost and expenses	9,028		11,124		3,564		169		10		23,895

Gain on sale of assets	19		—		17		211		—		247
Operating income	1,286		1,901		112		42		—		3,341
Equity in (losses)/earnings of unconsolidated affiliates	(3)		—		20		—		—		17

Other income, net	8		7		3		59		(14)		63
Loss on debt extinguishment	—		—		—		(77)		—		(77)
Interest expense	(1)		(1)		(28)		(469)		14		(485)
Income/(loss) before income taxes	1,290		1,907		107		(445)		—		2,859
Income tax expense	—		—		19		653		—		672




Net income/(loss)	$	1,290	$	1,907	$	88	$	(1,098)	$	—	$	2,187

Balance sheet
Equity investments in affiliates	$	—	$	—	$	157	$	—	$	—	$	157
Capital expenditures	153		50		21		45		—		269
Goodwill	716		853		226		—		—		1,795
Total assets	$	12,271	$	13,645	$	4,673	$	19,051	$	(26,458)	$	23,182


(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues			$	5					$	(18)					$	3					$	—					$	—					$	(10)


	For the Year Ended December 31, 2020
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenues(a)	$	6,312	$	2,249	$	536	$	—	$	(4)	$	9,093
Operating expenses	5,251		1,755		422		57		(4)		7,481
Depreciation and amortization	233		132		36		34		—		435
Impairment losses	14		—		61		—		—		75
Total operating cost and expenses	5,498		1,887		519		91		(4)		7,991

(Loss)/gain on sale of assets	—		—		(2)		5		—		3
Operating income/(loss)	814		362		15		(86)		—		1,105
Equity in (losses)/earnings of unconsolidated affiliates	(12)		—		29		—		—		17
Impairment losses on investments	(18)		—		—		—		—		(18)
Other income, net	11		7		8		41		—		67
Loss on debt extinguishment	—		(4)		(5)		—		—		(9)
Interest expense	—		(14)		(3)		(384)		—		(401)
Income/(loss) before income taxes	795		351		44		(429)		—		761
Income tax (benefit)/expense	—		(1)		2		250		—		251
Net income/(loss)	$	795	$	352	$	42	$	(679)	$	—	$	510


(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues			$	6					$	(6)					$	4					$	—					$	—					$	4

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI https://asc.fasb.org/extlink&oid=126901519&loc=d3e8924-108599

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+ Details

Income Taxes

12 Months Ended

Dec. 31, 2022

Income Tax Disclosure [Abstract]

Income Taxes

The income tax provision consisted of the following amounts:


	Year Ended December 31,
(In millions, except effective income tax rate)	2022			2021			2020
Current
U.S. Federal	$	3		$	—		$	—
State	65			48			22
Foreign	3			3			4
Total — current	71			51			26
Deferred
U.S. Federal	258			569			168
State	59			36			60
Foreign	54			16			(3)
Total — deferred	371			621			225
Total income tax expense	$	442		$	672		$	251
Effective income tax rate	26.6		%	23.5		%	33.0		%

The IRA enacted on August 16, 2022, introduced new provisions including a 15% corporate book minimum tax and a 1% excise tax on net share repurchases with both taxes effective beginning in fiscal year 2023 for NRG. The Company will continue to evaluate the impact of the corporate book minimum tax when the U.S. Treasury and the IRS release further guidance. Additionally, the IRA establishes a production tax credit associated with existing nuclear facilities which begins in 2024 and terminates at the end of 2031. The production tax credit will fully apply when gross revenues are at or below $25 per MWh and phases out completely at $43.75 per MWh. The U.S. Treasury is in the process of defining the methods by which gross revenues may be calculated pursuant to the IRA.

On March 27, 2020, the Senate passed the CARES Act to provide emergency relief related to the COVID-19 pandemic. The CARES Act contains federal income tax provisions which, among other things: (i) increases the amount of interest expense that businesses are allowed to deduct by increasing the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 and 2020; (ii) permits businesses to carry back to each of the five tax years NOLs arising from tax years beginning after December 31, 2017 and before January 1, 2020; and (iii) temporarily removes the 80% limitation on NOLs until tax years beginning after 2020. The CARES Act provisions did not have a material impact on the tax positions of the Company.

The following represented the domestic and foreign components of income before income taxes:


	Year Ended December 31,
(In millions)	2022		2021		2020
U.S.	$	1,436	$	2,759	$	749
Foreign	227		100		12
Total	$	1,663	$	2,859	$	761

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)	2022			2021			2020
Income before income taxes	$	1,663		$	2,859		$	761
Tax at federal statutory tax rate	349			600			160
Foreign rate differential	7			(3)			—
State taxes	69			111			18

Permanent differences	17			8			8
Changes in valuation allowance	(3)			(29)			24


Deferred impact of state tax rate changes	14			(10)			2

Recognition of uncertain tax benefits	8			(10)			3
Carbon capture tax credits	(19)			—			—
Return to provision adjustments	—			5			36





Income tax expense	$	442		$	672		$	251
Effective income tax rate	26.6		%	23.5		%	33.0		%

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.

For the year ended December 31, 2021, 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 tax benefits from the revaluation of state deferred tax assets, valuation allowance, and settlements of uncertain tax positions.

For the year ended December 31, 2020, NRG's effective income tax rate was higher than the federal statutory tax rate of 21% primarily due to state tax expense, the recognition of state valuation allowance on NOLs, and return to provision adjustments.

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)	2022		2021
Deferred tax assets:
Deferred compensation, accrued vacation and other reserves	$	93	$	114
Difference between book and tax basis of property	399		436


Pension and other postretirement benefits	62		65
Equity compensation	8		7
Allowance for credit losses	33		168

U.S. Federal net operating loss carryforwards	1,717		1,773
Foreign net operating loss carryforwards	104		112
State net operating loss carryforwards	315		328

Federal and state tax credit carryforwards	393		384
Federal benefit on state uncertain tax positions	5		3

Interest disallowance carryforward per §163(j) of the Tax Act	65		6
Inventory obsolescence	10		9
U.S. capital loss	15		—
Other	22		15

Total deferred tax assets	3,241		3,420
Deferred tax liabilities:
Emissions allowances	19		20


Derivatives	874		591
Goodwill	26		40
Intangibles amortization (excluding goodwill)	269		363
Equity method investments	82		62

Convertible Debt	—		14


Total deferred tax liabilities	1,270		1,090
Total deferred tax assets less deferred tax liabilities	1,971		2,330
Valuation allowance	(224)		(248)

Total net deferred tax assets, net of valuation allowance	$	1,747	$	2,082

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


	As of December 31,
(In millions)	2022		2021
Deferred tax asset	$	1,881	$	2,155

Deferred tax liability	(134)		(73)
Net deferred tax asset	$	1,747	$	2,082

The primary drivers for the decrease in the net deferred tax asset from $2.1 billion as of December 31, 2021 to $1.7 billion as of December 31, 2022 is an increase in unrealized mark-to-market book gains on derivative instruments.

Deferred tax assets and valuation allowance

Net deferred tax balance — As of December 31, 2022 and 2021, NRG recorded a net deferred tax asset, excluding valuation allowance, of $2.0 billion and $2.3 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, 2022 as discussed below.

NOL carryforwards — As of December 31, 2022, the Company had tax-effected cumulative U.S. NOLs consisting of carryforwards for federal and state income tax purposes of $1.7 billion and $315 million, respectively. In addition, NRG has tax-effected cumulative foreign NOL carryforwards of $104 million. The majority of NRG's NOL carryforwards have no expiration date.

Valuation allowance — As of December 31, 2022, the Company's tax-effected valuation allowance was $224 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, 2022, NRG recorded a current net federal receivable of $5 million and a current net foreign receivable of $13 million due to filings of Canadian amended returns as well as prepayments of estimated taxes.

Uncertain tax benefits

NRG has identified uncertain tax benefits with after-tax value of $22 million and $13 million as of December 31, 2022 and 2021, for which NRG has recorded a non-current tax liability of $24 million and $14 million, respectively. The Company recognizes interest and penalties related to uncertain tax benefits in income tax expense. The Company recognized $1 million of interest expense for the year ended December 31, 2022, an immaterial amount for the year ended 2021 and $1 million for the year ended 2020. As of December 31, 2022 and 2021, NRG had cumulative interest and penalties related to these uncertain tax benefits of $2 million and $1 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 2019. With few exceptions, state and Canadian income tax examinations are no longer open for years before 2014.

The following table summarizes uncertain tax benefits activity:


	As of December 31,
(In millions)	2022		2021
Balance as of January 1	$	13	$	15
Increase due to current year positions	9		4
Increase due to acquired balance from Direct Energy	—		9

Settlements, payments and statute closure	—		(15)
Uncertain tax benefits as of December 31	$	22	$	13

- Definition

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
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-Paragraph 21
-URI https://asc.fasb.org/extlink&oid=121826272&loc=d3e32857-109319

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
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+ Details

Stock-Based Compensation

12 Months Ended

Dec. 31, 2022

Share-Based Payment Arrangement, Noncash Expense [Abstract]

Stock-Based Compensation

NRG Energy, Inc. Long-Term Incentive Plan

On April 27, 2017, the NRG LTIP was amended to increase the number of shares available for issuance by 3,000,000. As of December 31, 2022 and 2021, a total of 25,000,000 shares of NRG common stock were authorized for issuance under the NRG LTIP. There were 8,179,771 and 8,871,874 shares of common stock remaining available for grants under the NRG LTIP as of December 31, 2022 and 2021, 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.

Restricted Stock Units

As of December 31, 2022, RSUs granted under the Company's LTIPs typically have three-year graded vesting schedules beginning on the grant date. Fair value of the RSUs granted during 2022 and 2021 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, 2021	669,952	$	38.69
Granted	530,565	41.26
Forfeited	(43,601)	41.09
Vested	(299,999)	38.36

Non-vested at December 31, 2022	856,917	40.25

The total fair value of RSUs vested during the years ended December 31, 2022, 2021 and 2020 was $10 million, $12 million and $17 million, respectively. The weighted average grant date fair value of RSUs granted during the years ended December 31, 2022, 2021 and 2020 was $41.26, $39.00 and $38.05, 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 Company's LTIPs 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, 2021	384,128	$	26.11
Granted	52,865	45.49

Converted to Common Stock	(18,979)	39.27

Outstanding at December 31, 2022	418,014	27.63

The aggregate intrinsic values for DSUs outstanding as of December 31, 2022, 2021 and 2020 were approximately $13 million, $17 million and $13 million, respectively. The aggregate intrinsic values for DSUs converted to common stock for the years ended December 31, 2022, 2021 and 2020 were $1 million, $1 million and $2 million, respectively. The weighted average grant date fair value of DSUs granted during the years ended December 31, 2022, 2021 and 2020 was $45.49, $32.27 and $35.59, 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, or TSR, relative to the TSR of the Company's current proxy peer group and the total returns of select indexes, or Peer Group. For RPSU's granted in 2022 and forward, 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.

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, 2021	730,505	$	47.40
Granted	291,852	57.41
Forfeited	(54,392)	46.68
Vested	(172,630)	45.77
Non-vested at December 31, 2022	795,335	50.23

The weighted average grant date fair value of RPSUs granted during the years ended December 31, 2022, 2021 and 2020, was $57.41, $46.78 and $23.75, 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:


	2022		2021(a)		2020
	RPSUs		RPSUs		RPSUs
Expected volatility	37.54	%	34.05	%	30.15	%
Expected term (in years)	3		3		3
Risk free rate	0.97	%	0.17	%	1.58	%

(a)Assumptions pertain to the main award granted in January 2021. Additional 60,815 RPSUs were granted in September 2021 with a risk free rate of 0.42% and expected volatility of 37.38%

For the years ended December 31, 2022 and 2021, 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.

Non-Qualified Stock Options

All NQSOs granted under the Company's LTIP were fully vested as of December 31, 2022, 2021 and 2020. No NQSOs were granted in 2022, 2021 or 2020. Of the 17,870 NQSOs that were outstanding at December 31, 2021, 14,477 were exercised during the year ended December 31, 2022 and 3,393 expired. No compensation expense was recognized during 2022, 2021 or 2020 related to NQSOs.

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, 2022, for each of the types of awards issued under the LTIPs. Minimum tax withholdings of $6 million, $9 million, and $27 million for the years ended December 31, 2022, 2021, and 2020, 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	2022		2021		2020		2022		2022

RSUs	$	15	$	9	$	9	$	17	1.75
DSUs	2		2		2		—		0.00

RPSUs	11		9		10		13		1.16
PRSUs(a)	6		7		6		7		1.45
Total	$	34	$	27	$	27	$	37
Tax detriment/(benefit) recognized	$	3	$	2	$	(9)

(a)Phantom Restricted Stock Units, PRSUs, are liability-classified time-based awards that typically vest ratably over a three-year period. The amount to be paid upon vesting is based on NRG's closing stock price for the period

Related Party Transactions

12 Months Ended

Dec. 31, 2022

Related Party Transactions

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)	2022		2021		2020
Revenues from Related Parties Included in Revenues
Gladstone	$	4	$	4	$	4
Ivanpah(a)	42		39		43
Midway-Sunset	6		6		5
Total	$	52	$	49	$	52

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

Commitments and Contingencies

12 Months Ended

Dec. 31, 2022

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Certain Fuel and Transportation Commitments

NRG has entered into long-term contractual arrangements to procure certain fuel and transportation services for the Company's generation assets.

As of December 31, 2022, the Company's minimum commitments under such outstanding agreements are estimated as follows:


Period	(In millions)
2023	$	110
2024	71
2025	83
2026	54
2027	78
Thereafter	56
Total(a)	$	452

(a)Actual fuel and transportation purchases are 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, 2022, 2021 and 2020, the costs of certain fuel and transportation were $736 million, $584 million and $479 million, respectively.

Purchased Energy Commitments

NRG has long-term contractual commitments related to electricity and natural gas products, including power purchases, gas transportation and storage of various quantities and durations. These contracts are not included in the consolidated balance sheet as of December 31, 2022. Minimum purchase commitment obligations are as follows as of December 31, 2022:


Period	(In millions)
2023	$	908
2024	1,050
2025	662
2026	396
2027	296
Thereafter	987
Total(a)	$	4,299

(a)Actual energy purchases are significantly higher than these estimated minimum unconditional long-term firm commitments with remaining term in excess of one year. The year ending 2023 does not include an additional $1.5 billion of short-term commitments

For the years ended December 31, 2022, 2021 and 2020, the costs of purchased energy were $18.8 billion, $12.8 billion and $1.8 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, 2022, hedges under the first lien were out-of-the-money for NRG on a counterparty aggregate basis.

Nuclear Insurance

STP maintains required insurance coverage for liability claims arising from nuclear incidents pursuant to the Price-Anderson Act. The current liability limit per incident is $13.7 billion, subject to change to account for the effects of inflation and the number of licensed reactors. An inflation adjustment must be made at least once every five years with the next adjustment expected to be effective no later than November 1, 2023. Under the Price-Anderson Act, owners of nuclear power plants in the U.S. are required to purchase primary insurance limits of $450 million for each operating site. In addition, the Price-Anderson Act requires an additional layer of protection through mandatory participation in a retrospective rating plan for power reactors resulting in an additional $13.2 billion in funds available for public liability claims. The current maximum

assessment per incident, per reactor, is approximately $138 million, taking into account a 5% adjustment for administrative fees, payable at approximately $21 million per reactor, per incident, per year. NRG would be responsible for 44% of the maximum assessment, or $9 million per reactor, per incident, per year, and a maximum of $61 million per incident, per reactor. In addition, the U.S. Congress retains the ability to impose additional financial requirements on the nuclear industry to pay liability claims that exceed $13.7 billion for a single incident. The liabilities of the co-owners of STP with respect to the retrospective premium assessments for nuclear liability insurance are joint and several.

STP purchases insurance for property damage and site decontamination cleanup costs from Nuclear Electric Insurance Limited, or NEIL, and European Mutual Association for Nuclear Insurance, or EMANI, both of which are industry mutual insurance companies, of which STP is a member. STP has purchased $2.8 billion in limits for nuclear events and $1.0 billion in limits for non-nuclear events. The nuclear event limit remains the maximum available from NEIL. The upper $1.3 billion in nuclear events limits (excess of the first $1.5 billion in nuclear events limits) is a single limit blanket policy shared with two Diablo Canyon nuclear reactors, which have no affiliation with the Company. This shared limit is not subject to automatic reinstatement in the event of a loss. The NEIL primary policy covers both nuclear and non-nuclear property damage events, and a NEIL companion policy provides Accidental Outage coverage for the co-owners of STP's lost revenue following a property damage event, at a weekly indemnity limit of $3 million per unit up to a maximum of $274 million nuclear per unit and $183 million non-nuclear per unit, and is subject to an eight-week waiting period. NRG also purchases an Accidental Outage policy from NEIL, which provides protection for lost revenue due to an insurable event. This coverage allows for reimbursement up to $2 million per week per unit up to a maximum of $216 million nuclear and $144 million non-nuclear, and is subject to an eight-week waiting period. Accidental Outage coverage amounts decrease in the event more than one unit at a station is out of service due to a common accident. Under the terms of the NEIL and EMANI policies, member companies may be assessed up to ten and six times their annual premiums, respectively, if the NEIL or EMANI Board of Directors determines their surplus has been depleted due to the payment of property losses at any of the licensed reactors in a single policy year. NEIL and EMANI require that their members maintain an investment grade credit rating or ensure their annual retrospective obligation by providing a financial guarantee, letter of credit, deposit premium, or an insurance policy. NRG has purchased an insurance policy from NEIL and EMANI to guarantee the Company's obligation; however note the NEIL aspect of this insurance will only respond to retrospective premium adjustments assessed within twenty-four months after the policy term, whereas NEIL's Board of Directors can make such an adjustment up to 6 years after the policy expires. All insurance coverage is subject to various sub limits and significant deductibles.

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 24, Regulatory Matters, and Note 25, 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 granted in part and denied in part on February 6, 2020. The IPCB will hold hearings to determine 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 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 Cases — In the cases set forth below, referred to as the Variable Price Cases, such actions involve consumers alleging that one of the Company’s ESCOs 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 underlying claims of each case are similar and the Company continues to deny the allegations and is vigorously defending these matters. These matters were known and accrued for at the time of each acquisition.

XOOM Energy

XOOM Energy is a defendant in a putative class action lawsuit pending in New York. This case is in the summary judgment phase.

Direct Energy

There are four putative class actions pending against Direct Energy: (1) Linda Stanley v. Direct Energy (S.D.N.Y Apr. 2019) - The parties mediated in June 2021 and agreed on a settlement. In April 2022, the Court granted final approval of the settlement, which was primarily paid during the second quarter of 2022. This matter is complete and final; (2) Martin Forte v. Direct Energy (N.D.N.Y. Mar. 2017) - In December 2017, the Court granted Direct Energy's Motion for summary judgment effectively ending the matter at the district court level. Forte appealed. Direct Energy participated in oral argument on January 12, 2023. The Second Circuit Court of Appeals recently issued an opinion in Direct Energy's favor; (3) Richard Schafer v. Direct Energy (W.D.N.Y. Dec. 2019; on appeal 2nd Cir. N.Y.) - The Second Circuit sent the matter back to the trial court in December 2021. After discovery, Direct Energy filed summary judgement. Direct Energy won summary judgment and Schafer appealed. The parties are now briefing the appeal. Given the result in the Forte case, the trial court's summary judgment will be upheld and Direct Energy is expected to prevail; and (4) Andrew Gant v. Direct Energy and NRG (D.N.J. Aug. 2022) - Direct Energy and NRG filed a Motion to Dismiss on October 18, 2022.

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 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 October 19, 2022, Direct Energy filed a Motion to Transfer Venue asking the Court to transfer the case to the Southern District where the Burk case was filed. Direct Energy will await the court's ruling before moving forward 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 Court held oral arguments on January 17, 2023. Direct Energy anticipates a ruling within the next six months.

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 severed from the multi-district litigation and will be seeking dismissal in any remaining cases. 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 case is currently stayed pending appeal by other parties on other issues. The Company intends to vigorously defend these matters.

Indemnifications and Other Contractual Arrangements

Washington-St. Tammany and Claiborne Electric Cooperative v. LaGen — On June 28, 2017, plaintiffs Washington-St. Tammany Electric Cooperative, Inc. and Claiborne Electric Cooperative, Inc. filed a lawsuit against LaGen in the United States District Court for the Middle District of Louisiana. The plaintiffs claimed breach of contract against LaGen for allegedly improperly charging the plaintiffs for costs related to the installation and maintenance of certain pollution control technology. Plaintiffs sought damages for the alleged improper charges and a declaration as to which charges were proper under the contract. In February 2020, the federal court dismissed this lawsuit without prejudice for lack of subject matter jurisdiction. On March 17, 2020, plaintiffs filed a lawsuit in the Nineteenth Judicial District Court for the Parish of East Baton Rouge in Louisiana alleging substantially the same matters. On February 4, 2019, NRG sold the South Central Portfolio, including the entities subject to this litigation. However, NRG has agreed to indemnify the purchaser for certain losses suffered in connection therewith.

Regulatory Matters	12 Months Ended
Regulatory Matters	Dec. 31, 2022
Regulatory Matters Disclosure [Abstract]
Regulatory Matters	Regulatory 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 proceeding 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.

Environmental Matters	12 Months Ended
Environmental Matters	Dec. 31, 2022
Environmental Remediation Obligations [Abstract]
Environmental Matters	Environmental Matters 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 requirements regarding air quality, GHG emissions, combustion byproducts, water discharge and use, and threatened and endangered species. 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 — On July 8, 2019, the EPA promulgated the ACE rule, which rescinded the CPP, which had sought to broadly regulate CO2 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. The Company anticipates that there will be additional proceedings at the D.C. Circuit and additional rulemaking by the EPA over the next several years. Cross-State Air Pollution Rule ("CSAPR") — In April 2022, the EPA proposed revising the CSAPR to address the good-neighbor provisions of the 2015 ozone NAAQS. If the rule were finalized as proposed, it would apply to 25 states (including Texas) beginning in 2023. In 2023, the revised Group 3 trading program (previously established in the Revised CSAPR Update Rule) would have emission budgets based on NOx emission rates that the EPA says are achievable by existing controls at power plants. Starting in 2026, the NOx budgets would be reduced significantly based on levels achievable if SCR controls were installed at coal-fueled power plants that do not currently have such controls. Starting in 2025, the budgets would be updated annually to account for retirements, changes to operations and new units. The proposal also contemplates heightened surrender requirements for units that exceed certain NOx emission rate thresholds. The Company cannot predict the outcome of this proposed revision and anticipates that this rulemaking will be subject to legal challenges after it is finalized. The EPA anticipates finalizing the revised rule in Spring 2023. Water Effluent Limitations Guidelines — In November 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. On July 26, 2021, the EPA announced that it is initiating a new rulemaking to evaluate revising the ELG rule. While the EPA is developing the new rule, the existing rule (as amended in 2020) will stay in place, and the EPA expects permitting authorities to continue to implement the current regulation. The Company anticipates that the EPA will release a proposed rule in the first half of 2023. In October 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. Byproducts, Wastes, Hazardous Materials and Contamination In April 2015, the EPA finalized the rule regulating byproducts of coal combustion (e.g., ash and gypsum) as solid wastes under the RCRA. On July 30, 2018, the EPA promulgated a rule that amended the ash rule by extending some of the deadlines and providing more flexibility for compliance. 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," which further amended the April 2015 Rule to, among other things, provide procedures for requesting approval to operate existing impoundments with an alternative liner. NRG anticipates further rulemaking related to the Federal Permit Program and legacy surface impoundments.

- Definition

The entire disclosure for environmental loss contingencies, such as presence of hazardous waste, relevant information from reports issued by regulators, and estimated costs to achieve compliance with regulatory requirements. This element may be used for all of an entity's disclosures about environmental loss contingencies.

+ References

Reference 1: http://www.xbrl.org/2003/role/recommendedDisclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
-SubTopic 30
-Section 50
-Paragraph 10
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-URI https://asc.fasb.org/extlink&oid=6393242&loc=d3e13237-110859

Reference 2: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
-SubTopic 30
-Section 55
-Paragraph 11
-URI https://asc.fasb.org/extlink&oid=6571209&loc=d3e13644-110860

Reference 3: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
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-SubTopic 30
-Section 55
-Paragraph 17
-URI https://asc.fasb.org/extlink&oid=6571209&loc=d3e13718-110860

Reference 4: http://www.xbrl.org/2003/role/recommendedDisclosureRef
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-Name Accounting Standards Codification
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-Section 50
-Paragraph 17
-URI https://asc.fasb.org/extlink&oid=6393242&loc=d3e13328-110859

Reference 5: http://www.xbrl.org/2003/role/recommendedDisclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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-SubTopic 30
-Section 50
-Paragraph 10
-Subparagraph (b)
-URI https://asc.fasb.org/extlink&oid=6393242&loc=d3e13237-110859

Reference 6: http://www.xbrl.org/2003/role/recommendedDisclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
-SubTopic 30
-Section 50
-Paragraph 10
-Subparagraph (d)(4)
-URI https://asc.fasb.org/extlink&oid=6393242&loc=d3e13237-110859

Reference 7: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
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-URI https://asc.fasb.org/extlink&oid=6571209&loc=d3e13703-110860

Reference 8: http://www.xbrl.org/2003/role/recommendedDisclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
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-Section 50
-Paragraph 10
-Subparagraph (d)(3)
-URI https://asc.fasb.org/extlink&oid=6393242&loc=d3e13237-110859

Reference 9: http://www.xbrl.org/2003/role/recommendedDisclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
-SubTopic 30
-Section 50
-Paragraph 14
-URI https://asc.fasb.org/extlink&oid=6393242&loc=d3e13319-110859

Reference 10: http://www.xbrl.org/2003/role/recommendedDisclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
-SubTopic 30
-Section 50
-Paragraph 10
-Subparagraph (a)
-URI https://asc.fasb.org/extlink&oid=6393242&loc=d3e13237-110859

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
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-URI https://asc.fasb.org/subtopic&trid=2175709

Reference 12: http://www.xbrl.org/2003/role/recommendedDisclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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-Paragraph 10
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-URI https://asc.fasb.org/extlink&oid=6393242&loc=d3e13237-110859

Reference 13: http://www.xbrl.org/2003/role/recommendedDisclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
-SubTopic 30
-Section 50
-Paragraph 10
-Subparagraph (c)
-URI https://asc.fasb.org/extlink&oid=6393242&loc=d3e13237-110859

Reference 14: http://www.xbrl.org/2003/role/recommendedDisclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
-SubTopic 30
-Section 50
-Paragraph 11
-URI https://asc.fasb.org/extlink&oid=6393242&loc=d3e13283-110859

+ Details

Cash Flow Information

12 Months Ended

Dec. 31, 2022

Supplemental Cash Flow Information [Abstract]

Cash Flow Information

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


	Year Ended December 31,
(In millions)	2022		2021		2020
Interest paid, net of amount capitalized	$	383	$	433	$	340
Income taxes paid, net of refunds	66		32		24
Non-cash investing activities:
Decreases to fixed assets for accrued capital expenditures	(68)		(16)		(6)

Guarantees

12 Months Ended

Dec. 31, 2022

Guarantees [Abstract]

Guarantees

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)	2022
Guarantees	Under 1 Year		1-3 Years		3-5 Years		Over 5 Years		Total		2021 Total
Letters of credit and surety bonds	$	5,211	$	—	$	—	$	—	$	5,211	$	4,095
Asset sales guarantee obligations	270		25		34		80		409		414
Other guarantees	—		—		—		15		15		93
Total guarantees	$	5,481	$	25	$	34	$	95	$	5,635	$	4,602

Letters of credit and surety bonds — As of December 31, 2022, NRG and its consolidated subsidiaries were contingently obligated for a total of $5.2 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.

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 NRG Yield for, as part of the agreement to sell NRG Yield and the Renewables Platform. The California property tax indemnity is estimated to be $141 million as of December 31, 2022 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.

Jointly Owned Plants

12 Months Ended

Dec. 31, 2022

Jointly Owned Plants Disclosure [Abstract]

Jointly Owned Plants

Certain NRG subsidiaries own undivided interests in jointly-owned plants, as described below. These plants are maintained and operated pursuant to their joint ownership participation and operating agreements. NRG is responsible for its subsidiaries' share of operating costs and direct expenses and includes its proportionate share of the facilities and related revenues and direct expenses in these jointly-owned plants 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 facilities:


(In millions unless otherwise stated)
As of December 31, 2022	Ownership Interest		Property, Plant & Equipment		Accumulated Depreciation		Construction in Progress
South Texas Project Units 1 and 2, Bay City, TX	44.00	%	$	478	$	(235)	$	7
Cedar Bayou Unit 4, Baytown, TX	50.00	%	229		(118)		7

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS

12 Months Ended

Dec. 31, 2022

SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS

For the Years Ended December 31, 2022, 2021 and 2020


(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
Year Ended December 31, 2022	$	683	$	11	$	—	$	(561)	(a)	$	133
Year Ended December 31, 2021	67		698		112		(194)		(a)	683
Year Ended December 31, 2020	43		108		—		(84)		(a)	67
Income tax valuation allowance, deducted from deferred tax assets
Year Ended December 31, 2022	$	248	$	(20)	$	(4)	$	—		$	224
Year Ended December 31, 2021	266		(29)		11		—			248
Year Ended December 31, 2020	242		24		—		—			266

(a) Represents principally net amounts charged as uncollectible

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2022

Accounting Policies [Abstract]

Basis of Presentation

Principles of Consolidation

Winter Storm Uri Uplift Securitization Proceeds

Credit Losses

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

Restricted Cash


	Year Ended December 31,
(In millions)	2022		2021		2020
Cash and cash equivalents	$	430	$	250	$	3,905
Funds deposited by counterparties	1,708		845		19
Restricted cash	40		15		6
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$	2,178	$	1,110	$	3,930

Restricted cash consists primarily of funds held to satisfy the requirements of certain financing agreements and funds held within the Company's projects that are restricted in their use.

Inventory

Property, Plant and Equipment

Business Interruption Insurance

Business Interruption InsuranceThe Company carries insurance policies to cover insurable risks including, but not limited to, business interruption.

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

Contract and Emission Credit Amortization

Retail Revenue

Energy Revenue

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

Gross Receipts and Sales Taxes

Cost of Operations, Cost of Fuel, Purchased Energy and Other Cost of Sales

Cost of Operations

Cost of Fuel, Purchased Energy and Other Cost of Sales

Derivative Instruments

As of December 31, 2022 and 2021 the Company did not have derivative instruments that were designated as cash flow or fair value hedge.

Mark-to-Market for Economic Hedging Activities

Operations, Maintenance and Other Costs of Operations

Operations and Maintenance and Other Cost of Operations

Foreign Currency Translation and Transaction Gains and Losses

Concentrations of Credit Risk

Fair Value of Financial Instruments

Asset Retirement Obligations

Pensions and Other Postretirement Benefits

The Company measures the fair value of its pension assets in accordance with ASC 820, Fair Value Measurements and Disclosures, or ASC 820.

Stock-Based Compensation

Investments Accounted for by the Equity Method

Investments Accounted for by the Equity MethodThe Company has investments in various 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.

Tax Equity Arrangements

Sale-Leaseback Arrangements

Marketing and Advertising Costs

Marketing and Advertising CostsThe Company expenses its marketing and advertising costs as incurred and includes them within selling, general and administrative expenses. 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.

Business Combinations

Use of 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

Recent Accounting Developments - Guidance Adopted in 2022

Recent Accounting Developments - Guidance Not Yet Adopted

Revenue Recognition

Contract and Emission Credit Amortization

Retail Revenue

Energy Revenue

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

Nuclear Decommissioning Policy

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2022

Accounting Policies [Abstract]

Accounts Receivable, Allowance for Credit Loss

The following table represents the activity in the allowance for credit losses for the years ended December 31, 2022, 2021, and 2020:


	Year Ended December 31,
(In millions)	2022		2021		2020
Beginning balance	$	683	$	67	$	43
Acquired balance from Direct Energy	—		112		—
Provision for credit losses(a)	11		698		108
Write-offs	(593)		(224)		(101)
Recoveries collected	32		30		17
Ending balance(a)	$	133	$	683	$	67

(a)Includes bilateral finance hedging risk of $(70) million and $403 million accounted for under ASC 815 for the years ended December 31, 2022 and December 31, 2021, respectively

Reconciliation of cash, cash equivalents, and restricted cash and cash equivalents


	Year Ended December 31,
(In millions)	2022		2021		2020
Cash and cash equivalents	$	430	$	250	$	3,905
Funds deposited by counterparties	1,708		845		19
Restricted cash	40		15		6
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$	2,178	$	1,110	$	3,930

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


	Year Ended December 31,
(In millions)	2022		2021		2020
Interest paid, net of amount capitalized	$	383	$	433	$	340
Income taxes paid, net of refunds	66		32		24
Non-cash investing activities:
Decreases to fixed assets for accrued capital expenditures	(68)		(16)		(6)

Revenue Recognition (Tables)

12 Months Ended

Dec. 31, 2022

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following tables represent the Company’s disaggregation of revenue from contracts with customers for the years ended December 31, 2022, 2021, and 2020:


	For the Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	6,388	$	2,088	$	2,286	$	(1)	$	10,761
Business	3,229		13,768		1,964		—		18,961
Total retail revenue(b)	9,617		15,856		4,250		(1)		29,722
Energy revenue(b)	111		641		466		32		1,250
Capacity revenue(b)	—		232		40		—		272
Mark-to-market for economic hedging activities(c)	2		(30)		(56)		1		(83)
Contract amortization	—		(40)		1		—		(39)
Other revenue(b)	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) Home includes Services
(b) The following amounts of retail, energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(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)
(c) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815


	For the Year Ended December 31, 2021
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	5,659	$	1,832	$	2,059	$	(1)	$	9,549
Business	2,745		10,030		1,237		—		14,012
Total retail revenue	8,404		11,862		3,296		(1)		23,561
Energy revenue(c)	329		508		371		7		1,215
Capacity revenue(c)	—		718		57		—		775
Mark-to-market for economic hedging activities(d)	(3)		(88)		(86)		13		(164)
Contract amortization	—		(26)		(4)		—		(30)
Other revenue(b)(c)	1,565		51		25		(9)		1,632
Total revenue	10,295		13,025		3,659		10		26,989
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		(25)		3		—		(22)
Less: Realized and unrealized ASC 815 revenue	130		184		(96)		16		234
Total revenue from contracts with customers	$	10,165	$	12,866	$	3,752	$	(6)	$	26,777
(a) Home includes Services
(b) Other Revenue in Texas includes ancillary revenues of $1.3 billion driven by high pricing during Winter Storm Uri
(c) The following amounts of energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Energy revenue	$	—	$	131	$	2	$	3	$	136
Capacity revenue	—		149		—		—		149
Other revenue	133		(8)		(12)		—		113
(d) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815


	For the Year Ended December 31, 2020
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	5,020	$	1,210	$	103	$	(2)	$	6,331
Business	1,034		95		—		—		1,129
Total retail revenue	6,054		1,305		103		(2)		7,460
Energy revenue(b)	24		183		333		(1)		539
Capacity revenue(b)	—		620		61		(1)		680
Mark-to-market for economic hedging activities(c)	2		88		(3)		8		95
Contract amortization	—		—		—		—		—
Other revenue(b)	232		53		42		(8)		319
Total revenue	6,312		2,249		536		(4)		9,093
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		1		17		—		18
Less: Realized and unrealized ASC 815 revenue	30		314		38		3		385
Total revenue from contracts with customers	$	6,282	$	1,934	$	481	$	(7)	$	8,690
(a) Home includes Services
(b) The following amounts of energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Energy revenue	$	—	$	67	$	43	$	(5)	$	105
Capacity revenue	—		156		—		—		156
Other revenue	28		3		(2)		—		29
(c) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

Contract Assets and Liabilities

The following table reflects the contract assets and liabilities included in the Company's balance sheet as of December 31, 2022 and 2021:


(In millions)	December 31, 2022		December 31, 2021
Deferred customer acquisition costs	$	126	$	133

Accounts receivable, net - Contracts with customers	4,704		3,057
Accounts receivable, net - Accounted for under topics other than ASC 606	64		182
Accounts receivable, net - Affiliate	5		6
Total accounts receivable, net	$	4,773	$	3,245

Unbilled revenues (included within Accounts receivable, net - Contracts with customers)	$	1,952	$	1,574

Deferred revenues (a)	$	186	$	227

(a) Deferred revenues from contracts with customers for the years ended December 31, 2022 and 2021 were approximately $175 million and $224 million, respectively

Acquisitions and Dispositions (Tables)

12 Months Ended

Dec. 31, 2022

Discontinued Operations and Disposal Groups [Abstract]

Schedule of Purchase Price Allocation

The purchase price was allocated as follows as of December 31, 2021:


	(In millions)
Current Assets
Cash and cash equivalents	$	152
Funds deposited by counterparties	21
Restricted cash	9
Accounts receivable, net	1,802
Inventory	106
Derivative instruments	1,014
Cash collateral paid in support of energy risk management activities	233
Prepayments and other current assets	173
Total current assets	3,510


	(In millions)
Property, plant and equipment, net	151
Other Assets
Goodwill(a)	1,250
Intangible assets, net:
Customer relationships(b)	1,277
Customer and supply contracts(b)	610
Trade names(b)	310
Renewable energy credits	124
Total intangible assets, net	2,321
Derivative instruments	531
Other non-current assets	31
Total other assets	4,133
Total Assets	$	7,794

Current Liabilities
Accounts payable	$	1,116
Derivative instruments	1,266
Cash collateral received in support of energy risk management activities	21
Accrued expenses and other current liabilities	670
Total current liabilities	3,073
Other Liabilities
Derivative instruments	562
Deferred income taxes	320
Other non-current liabilities	115
Total other liabilities	997
Total Liabilities	$	4,070

Direct Energy Purchase Price	$	3,724

(b)As of January 5, 2021, the weighted average amortization period for total amortizable intangible assets was 12 years

Fair Value of Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2022

Fair Value Disclosures [Abstract]

Estimated Carrying Amounts and Fair Values of Financial Instruments Not Carried at Fair Value

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


	As of December 31,
	2022				2021
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value



Convertible Senior Notes	$	575	$	576	$	518	$	677
Other long-term debt, including current portion	7,523		6,432		7,522		7,650
Total long-term debt, including current portion (a)	$	8,098	$	7,008	$	8,040	$	8,327

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

Assets and Liabilities Measured and Recorded at Fair Value Measured on a Recurring Basis


	As of December 31, 2022
	Fair Value
(In millions)	Total		Level 1		Level 2		Level 3
Investments in securities (classified within other current and non-current assets)	$	19	$	—	$	19	$	—

Nuclear trust fund investments:
Cash and cash equivalents	15		15		—		—
U.S. government and federal agency obligations	86		84		2		—
Federal agency mortgage-backed securities	101		—		101		—
Commercial mortgage-backed securities	35		—		35		—
Corporate debt securities	114		—		114		—
Equity securities	403		403		—		—
Foreign government fixed income securities	1		—		1		—
Other trust fund investments (classified within other non-current assets):
U.S. government and federal agency obligations	1		1		—		—
Derivative assets:
Foreign exchange contracts	18		—		18		—
Commodity contracts	11,976		1,929		8,796		1,251


Measured using net asset value practical expedient:
Equity securities - nuclear trust fund investments	83
Equity securities (classified within other non-current assets)	6
Total assets	$	12,858	$	2,432	$	9,086	$	1,251
Derivative liabilities:
Foreign exchange contracts	$	2	$	—	$	2	$	—
Commodity contracts	8,439		1,244		6,449		746

Total liabilities	$	8,441	$	1,244	$	6,451	$	746


	As of December 31, 2021
	Fair Value
(In millions)	Total		Level 1		Level 2		Level 3
Investments in securities (classified within other current or non-current assets)	$	32	$	15	$	17	$	—
Nuclear trust fund investments:
Cash and cash equivalents	33		33		—		—
U.S. government and federal agency obligations	112		111		1		—
Federal agency mortgage-backed securities	100		—		100		—
Commercial mortgage-backed securities	44		—		44		—
Corporate debt securities	122		—		122		—
Equity securities	494		494		—		—
Foreign government fixed income securities	4		—		4		—
Other trust fund investments (classified within other non-current assets):
U.S. government and federal agency obligations	1		1		—		—
Derivative assets:
Foreign exchange contracts	1		—		1		—
Commodity contracts	7,139		981		5,701		457


Measured using net asset value practical expedient:
Equity securities - nuclear trust fund investments	99
Equity securities (classified within other non-current assets)	7
Total assets	$	8,188	$	1,635	$	5,990	$	457
Derivative liabilities:
Foreign exchange contracts	$	1	$	—	$	1	$	—
Commodity contracts	4,798		626		4,008		164

Total liabilities	$	4,799	$	626	$	4,009	$	164

Reconciliation of Beginning and Ending Balances for Financial Instruments that are Recognized at Fair Value using Significant Unobservable Inputs


	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Derivatives (a)
	For the Year Ended December 31,
(In millions)	2022		2021
Beginning balance	$	293	$	(16)
Contracts added from Direct Energy acquisition	—		(15)
Total gains realized/unrealized included in earnings	53		145

Purchases	(110)		93

Transfers into Level 3 (b)	264		71
Transfers out of Level 3 (b)	5		15
Ending balance	$	505	$	293
Gains 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	$	204	$	120

(a)Consists of derivatives assets and liabilities, net

(b)Transfers into/out of Level 3 are related to the availability of external broker quotes, and are valued as of the end of the reporting period. All transfers into/out of Level 3 are from/to Level 2

Schedule of Significant Unobservable Inputs used in Developing Fair Value of Level 3 Positions

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, 2022 and 2021:


	Significant Unobservable Inputs
	December 31, 2022
	Fair Value						Input/Range
(In millions)	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
Natural Gas Contracts	$	340	$	448	Discounted Cash Flow	Forward Market Price (per MMBtu)	$	2	$	48	$	6
Power Contracts	843		216		Discounted Cash Flow	Forward Market Price (per MWh)	3		431		48
FTRs	68		82		Discounted Cash Flow	Auction Prices (per MWh)	(32)		610		0
	$	1,251	$	746


	Significant Unobservable Inputs
	December 31, 2021
	Fair Value						Input/Range
(In millions)	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
Natural Gas Contracts	$	16	$	1	Discounted Cash Flow	Forward Market Price (per MMBtu)	$	3	$	40	$	15
Power Contracts	392		121		Discounted Cash Flow	Forward Market Price (per MWh)	3		212		35
FTRs	49		42		Discounted Cash Flow	Auction Prices (per MWh)	(122)		43		0
	$	457	$	164

Fair Value Inputs, Sensitivity Analysis

The following table provides sensitivity of fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2022 and 2021:

Significant Unobservable Input

Position

Change In Input

Impact on Fair Value Measurement

Forward Market Price Natural Gas/ Power

Buy

Increase/(Decrease)

Higher/(Lower)

Forward Market Price Natural Gas/Power

Sell

Increase/(Decrease)

Lower/(Higher)

FTR Prices

Buy

Increase/(Decrease)

Higher/(Lower)

FTR Prices

Sell

Increase/(Decrease)

Lower/(Higher)

Net Counterparty Credit Exposure by Industry Sector and by Counterparty Credit Quality

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	62	%
Financial institutions	38


Total	100	%


Category	Net Exposure (a) (b) (% of Total)
Investment grade	65	%
Non-Investment grade/Non-Rated	35

Total	100	%

(a)Counterparty credit exposure excludes uranium and 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

Accounting for Derivative Instruments and Hedging Activities (Tables)

12 Months Ended

Dec. 31, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Net Notional Volume Buy/(sell) of NRG's Open Derivative Transactions Broken Out By Commodity


(In millions)		Total Volume
Commodity	Units	December 31, 2022	December 31, 2021
Emissions	Short Ton	1	1
Renewables Energy Certificates	Certificates	15	13
Coal	Short Ton	11	19
Natural Gas	MMBtu	422	813
Oil	Barrels	1	1
Power	MWh	192	185



Foreign Exchange	Dollars	569	279

Fair Value Within the Derivative Instrument Valuation On the Balance Sheet

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, 2022		December 31, 2021		December 31, 2022		December 31, 2021






Derivatives Not Designated as Cash Flow or Fair Value Hedges:
Foreign exchange contracts - current	$	11	$	—	$	1	$	1
Foreign exchange contracts - long-term	7		1		1		—

Commodity contracts- current	7,875		4,613		6,194		3,386
Commodity contracts- long-term	4,101		2,526		2,245		1,412

Total Derivatives Not Designated as Cash Flow or Fair Value Hedges	$	11,994	$	7,140	$	8,441	$	4,799

Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received Or Paid

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, 2022
Foreign exchange contracts:
Derivative assets	$	18	$	(2)	$	—	$	16
Derivative liabilities	(2)		2		—		—
Total foreign exchange contracts	$	16	$	—	$	—	$	16
Commodity contracts:
Derivative assets	$	11,976	$	(7,897)	$	(1,659)	$	2,420
Derivative liabilities	(8,439)		7,897		20		(522)
Total commodity contracts	$	3,537	$	—	$	(1,639)	$	1,898






Total derivative instruments	$	3,553	$	—	$	(1,639)	$	1,914


	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, 2021
Foreign exchange contracts:
Derivative assets	$	1	$	(1)	$	—	$	—
Derivative liabilities	(1)		1		—		—
Total foreign exchange contracts	$	—	$	—	$	—	$	—
Commodity contracts:
Derivative assets	$	7,139	$	(4,440)	$	(831)	$	1,868
Derivative liabilities	(4,798)		4,440		17		(341)
Total commodity contracts	$	2,341	$	—	$	(814)	$	1,527




Total derivative instruments	$	2,341	$	—	$	(814)	$	1,527

Pre-tax Effects of Economic Hedges That Have Not Been Designated As Cash Flow Hedges, Ineffectiveness On Cash Flow Hedges And Trading Activity on the Company's Statement of Operations


	Year Ended December 31,
(In millions)	2022		2021		2020
Unrealized mark-to-market results
Reversal of previously recognized unrealized (gains) on settled positions related to economic hedges	$	(1,232)	$	(41)	$	(55)
Reversal of acquired loss positions related to economic hedges	2		256		4
Net unrealized gains/(losses) on open positions related to economic hedges	2,478		2,501		(68)
Total unrealized mark-to-market gains/(losses) for economic hedging activities	1,248		2,716		(119)
Reversal of previously recognized unrealized losses/(gains) on settled positions related to trading activity	13		(18)		(20)
Reversal of acquired (gain) positions related to trading activity	—		(1)		—

Net unrealized (losses)/gains on open positions related to trading activity	(17)		(13)		15
Total unrealized mark-to-market (losses) for trading activity	(4)		(32)		(5)
Total unrealized gains/(losses)	$	1,244	$	2,684	$	(124)


	Year Ended December 31,
(In millions)	2022		2021		2020
Unrealized (losses)/gains included in operating - commodities	$	(87)	$	(196)	$	90
Unrealized gains/(losses) included in cost of operations - commodities	1,315		2,880		(214)
Unrealized gains included in cost of operations - foreign exchange	16		—		—
Total impact to statement of operations	$	1,244	$	2,684	$	(124)

Nuclear Decommissioning Trust Fund (Tables)

12 Months Ended

Dec. 31, 2022

Regulated Operations [Abstract]

Summary of Aggregate Fair Values and Unrealized Gains And Losses (Including Other-Than-Temporary Impairments) for the Securities Held in The Nuclear Decommissioning Trust Fund


	As of December 31, 2022							As of December 31, 2021
(In millions, except otherwise noted)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted- average maturities (in years)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted- average maturities (in years)
Cash and cash equivalents	$	15	$	—	$	—	—	$	33	$	—	$	—	—
U.S. government and federal agency obligations	86		—		5		11	112		5		1		10
Federal agency mortgage-backed securities	101		—		11		26	100		2		—		25
Commercial mortgage-backed securities	35		—		4		30	44		1		—		27
Corporate debt securities	114		—		13		12	122		7		1		14
Equity securities	486		346		3		—	593		456		—		—
Foreign government fixed income securities	1		—		—		17	4		—		—		13
Total	$	838	$	346	$	36		$	1,008	$	471	$	2

Summary of Proceeds From Sales of Available-For-Sale securities and the related realized gains and losses


	Year Ended December 31,
(In millions)	2022		2021		2020
Realized gains	$	14	$	47	$	34
Realized losses	(25)		(9)		(13)
Proceeds from sale of securities	448		710		439

Inventory (Tables)

12 Months Ended

Dec. 31, 2022

Inventory Disclosure [Abstract]

Schedule of Inventory

Inventory consisted of:


	As of December 31,
(In millions)	2022		2021
Fuel oil	$	8	$	8
Coal	114		83
Natural gas	385		206
Spare parts and finished goods	244		201
Total Inventory	$	751	$	498

Property, Plant and Equipment (Tables)

12 Months Ended

Dec. 31, 2022

Property, Plant and Equipment [Abstract]

Major Classes of Property, Plant and Equipment

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


	As of December 31,				Depreciable
(In millions)	2022		2021		Lives
Facilities and equipment	$	1,727	$	1,742	1-40 years
Land and improvements	263		271
Nuclear fuel	271		222		5 years
Hardware and office equipment and furnishings	712		637		2-10 years
Construction in progress	197		124
Total property, plant, and equipment	3,170		2,996
Accumulated depreciation	(1,478)		(1,308)
Net property, plant, and equipment	$	1,692	$	1,688

Leases (Tables)

12 Months Ended

Dec. 31, 2022

Leases [Abstract]

Lease Cost

Lease Cost:


	For the Year Ended December 31,
(In millions)	2022		2021		2020
Finance lease cost	$	4	$	4	$	3


Operating lease cost	85		91		100
Short-term lease cost	7		3		3
Variable lease cost	86		9		6
Sublease income	(2)		(2)		(17)
Total lease cost	$	180	$	105	$	95

Other information:


	For the Year Ended December 31,
(In millions)	2022		2021		2020

Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	183	$	102	$	101

Financing cash flows from finance leases	5		6		1
Right-of-use assets obtained in exchange for new finance lease liabilities	3		16		5
Right-of-use assets obtained in exchange for new operating lease liabilities	28		47		4

Lease Term and Discount Rate for leases:


	December 31, 2022		December 31, 2021
Finance leases:
Weighted average remaining lease term (in years)	2.6		3.6
Weighted average discount rate	2.82	%	2.46	%

Operating leases:
Weighted average remaining lease term (in years)	4.3		4.7
Weighted average discount rate	5.37	%	5.44	%

Schedule of Annual Payments Based on Maturities of Leases

As of December 31, 2022, annual payments based on the maturities of NRG's operating leases are expected to be as follows:


	In millions
2023	$	97
2024	82
2025	56
2026	14
2027	10
Thereafter	52
Total undiscounted lease payments	$	311
Less: present value adjustment	(48)
Total discounted lease payments	$	263

Goodwill and Other Intangibles (Tables)

12 Months Ended

Dec. 31, 2022

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill

The table below presents the changes of goodwill for the years ended December 31, 2022 and 2021 based on the Company's reportable segments.


(in millions)	Texas		East		West/Services/Other		Total
Balance as of January 1, 2021	$	289	$	240	$	50	$	579
Goodwill resulted from the acquisition of Direct Energy	427		648		175		1,250
Impairment losses	—		(35)		—		(35)
Foreign currency translation	—		—		1		1
Balance as of December 31, 2021	$	716	$	853	$	226	$	1,795

Impairment losses	—		(130)		—		(130)
Asset sales	(6)		—		—		(6)
Foreign currency translation	—		—		(9)		(9)
Balance as of December 31, 2022	$	710	$	723	$	217	$	1,650

Summary of the Components of Intangible Assets Subject to Amortization

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


(In millions)
Year Ended December 31, 2022	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Trade Names		Other(b)		Total
January 1, 2022	$	634	$	638	$	1,679	$	284	$	683	$	229	$	4,147
Purchases	26		—		—		—		—		404		430
Acquisition of businesses (a)	—		—		55		—		—		—		55
Usage/Sales/Retirements	(33)		—		—		—		—		(341)		(374)
Write-off of fully amortized balances	(14)		—		—		—		—		—		(14)

Other	11		(3)		(4)		—		(4)		—		—
December 31, 2022	624		635		1,730		284		679		292		4,244
Less accumulated amortization	(528)		(235)		(787)		(146)		(341)		(75)		(2,112)
Net carrying amount	$	96	$	400	$	943	$	138	$	338	$	217	$	2,132

(a)The weighted average life of acquired amortizable intangibles was six years for customer relationships

(b)RECs are not subject to amortization and had a carrying value of $186 million


(In millions)
Year Ended December 31, 2021	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Trade Names		Other(b)		Total
January 1, 2021	$	672	$	28	$	527	$	285	$	373	$	140	$	2,025
Purchases	10		—		—		—		—		338		348
Acquisition of businesses (a)	—		610		1,308		—		310		124		2,352
Usage/Retirements	(1)		—		—		—		—		(364)		(365)
Write-off of fully amortized balances	(51)		—		(158)		—		—		(7)		(216)

Other	4		—		2		(1)		—		(2)		3
December 31, 2021	634		638		1,679		284		683		229		4,147
Less accumulated amortization	(536)		(94)		(518)		(123)		(294)		(71)		(1,636)
Net carrying amount	$	98	$	544	$	1,161	$	161	$	389	$	158	$	2,511

(a)The weighted average life of total acquired amortizable intangibles from the Direct Energy acquisition was 12 years

(b)RECs are not subject to amortization and had a carrying value of $123 million

Schedule of Amortization and Retirements of Intangible Expense

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


	Years Ended December 31,
(In millions)	2022		2021		2020
Emission allowances	$	6	$	24	$	28
Customer and supply contracts	141		66		12
Customer relationships	269		327		74
Marketing partnerships	23		24		24
Trade names	47		47		27
Other(a)	4		7		3
Total amortization	$	490	$	495	$	168

(a)For the years ended December 31, 2022, 2021 and 2020, other intangibles were amortized to depreciation and amortization expense for $4 million, $3 million and $3 million, respectively

Schedule of Estimated Amortization of Intangible Assets for Next Five Years

The following table presents estimated amortization of NRG's intangible assets as of December 31, 2022 for each of the next five years:


(In millions)
Year Ended December 31,	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Trade Names		Other		Total
2023	$	18	$	119	$	226	$	23	$	46	$	4	$	436
2024	19		73		159		23		38		3		315
2025	18		50		118		22		31		4		243
2026	10		52		103		22		23		3		213
2027	10		30		74		22		23		3		162

- Definition

Tabular disclosure of goodwill by reportable segment and in total which includes a rollforward schedule.

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+ Details

Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2022

Asset Retirement Obligation Disclosure [Abstract]

Schedule of ARO Obligations and Related Additions, Reductions and Accretion


(In millions)	Nuclear Decommission		Other(a)		Total
Balance as of December 31, 2021	$	321	$	399	$	720
Revisions in estimates for current obligations	—		38		38
Additions	—		1		1
Spending for current obligations	—		(33)		(33)
Accretion	19		19		38
Other	—		(6)		(6)
Balance as of December 31, 2022	$	340	$	418	$	758

Long-term Debt and Finance Leases (Tables)

12 Months Ended

Dec. 31, 2022

Debt Disclosure [Abstract]

Long-term Debt and Finance Leases

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


(In millions, except rates)	December 31, 2022		December 31, 2021		Interest rate %

Recourse debt:
Senior Notes, due 2027	$	375	$	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 2031	1,030		1,030		3.625
Senior Notes, due 2032	1,100		1,100		3.875
Convertible Senior Notes, due 2048(a)	575		575		2.750
Senior Secured First Lien Notes, due 2024	600		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

Tax-exempt bonds	466		466		1.250 - 4.750




Subtotal long-term debt (including current maturities)	8,100		8,100
Finance leases	11		13		various

Subtotal long-term debt and finance leases (including current maturities)	8,111		8,113
Less current maturities	(63)		(4)
Less debt issuance costs	(70)		(83)
Discounts	(2)		(60)
Total long-term debt and finance leases	$	7,976	$	7,966

Debt includes the following discounts:


	As of December 31,
(In millions)	2022		2021
Senior Secured First Lien Notes, due 2024, 2025, 2027 and 2029	$	(2)	$	(2)
Convertible Senior Notes, due 2048	—		(58)
Total discounts	$	(2)	$	(60)

Annual Payments Based On the Maturities of NRG's Debt

As of December 31, 2022, annual payments based on the maturities of NRG's debt and finance leases are expected to be as follows:


	(In millions)
2023	$	63
2024	604
2025	749
2026	1
2027	1,275
Thereafter	5,419
Total	$	8,111

Senior Note Redemptions


(In millions, except percentages)	Principal Repurchased		Cash Paid(a)		Average Early Redemption Percentage
7.250% Senior Notes, due 2026	$	1,000	$	1,056	103.625	%
6.625% Senior Notes, due 2027	855		893		103.313	%
Total	$	1,855	$	1,949

(a) Includes accrued interest of $29 million for redemptions for the year ended December 31, 2021


Redemption Period	Redemption Percentage
July 15, 2022 to July 14, 2023	102.208	%
July 15, 2023 to July 14, 2024	101.104	%
July 15, 2024 and thereafter	100.000	%


Redemption Period	Redemption Percentage
January 15, 2023 to January 14, 2024	102.875	%
January 15, 2024 to January 14, 2025	101.917	%
January 15, 2025 to January 14, 2026	100.958	%
January 15, 2026 and thereafter	100.000	%

In addition, on or after June 15, 2024, NRG 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 to the first applicable 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	%

In addition, on or after February 15, 2024, NRG 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 to the first applicable redemption date:


Redemption Period	Redemption Percentage
February 15, 2024 to February 14, 2025	101.688	%
February 15, 2025 to February 14, 2026	100.844	%
February 15, 2026 and thereafter	100.000	%

In addition, on or after February 15, 2026, NRG 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 to the first applicable 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	%

In addition, on or after February 15, 2027, NRG 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 to the first applicable 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	%

Schedule of Interest Expense, Convertible Senior Notes

The following table details the interest expense recorded in connection with the Convertible Senior Notes, due 2048:


	For the years ended December 31,
($ In millions)	2022			2021			2020
Contractual interest expense	$	16		$	16		$	16
Amortization of discount and deferred finance costs(a)	1			15			14
Total	$	17		$	31		$	30

Effective Interest Rate	3.01		%	5.34		%	5.19		%

(a)Upon adoption of ASU 2020-06 on January 1, 2022, which resulted in the removal of the debt discount, no further debt discount amortization is being recorded

Schedule of Tax Exempt Bonds

Tax Exempt Bonds


	As of December 31,
(In millions, except rates)	2022		2021		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		1.300
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

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

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+ Details

Benefit Plans and Other Postretirement Benefits (Tables)

12 Months Ended

Dec. 31, 2022

Retirement Benefits [Abstract]

Schedule of Net Benefit Cost (Credit) Related to Pension and Other Postretirement Benefit Plans Components

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)	2022		2021		2020
Service cost benefits earned	$	7	$	9	$	10
Interest cost on benefit obligation	41		27		38
Expected return on plan assets	(47)		(66)		(61)
Amortization of unrecognized net loss	3		1		5
Settlement/curtailment expense	14		2		—
Net periodic benefit cost/(credit)	$	18	$	(27)	$	(8)


	Year Ended December 31,
	Other Postretirement Benefits
(In millions)	2022		2021		2020

Interest cost on benefit obligation	$	2	$	2	$	3
Amortization of unrecognized prior service cost	(8)		(10)		(14)
Amortization of unrecognized net loss	2		1		1
Curtailment loss	—		1		—
Net periodic benefit credit	$	(4)	$	(6)	$	(10)

Schedule of Comparison of Pension Benefit obligation, Other Postretirement Benefit Obligations and Related Plan Assets on a Combined Basis

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)	2022		2021		2022		2021
Benefit obligation at January 1	$	1,452	$	1,489	$	105	$	90
Acquired benefit obligation from Direct Energy	—		74		—		19
Service cost	7		9		—		—
Interest cost	41		27		2		2

Actuarial gain	(289)		(55)		(11)		—
Employee and retiree contributions	—		—		3		3
Curtailment loss	—		—		—		1
Benefit payments	(171)		(93)		(15)		(10)
Foreign exchange translation	(4)		1		—		—
Benefit obligation at December 31	1,036		1,452		84		105
Fair value of plan assets at January 1	1,336		1,272		—		—
Acquired fair value of plan assets from Direct Energy	—		64		—		—
Actual return on plan assets	(317)		85		—		—
Employee and retiree contributions	—		—		3		3
Employer contributions	—		7		12		7
Benefit payments	(171)		(93)		(15)		(10)
Foreign exchange translation	(4)		1		—		—
Fair value of plan assets at December 31	844		1,336		—		—
Funded status at December 31 — excess of obligation over assets	$	(192)	$	(116)	$	(84)	$	(105)

Schedule of Amounts Recognized in Balance Sheet

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


	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2022		2021		2022		2021
Other current liabilities	$	—	$	—	$	7	$	7
Other non-current liabilities	192		116		77		98

Schedule of Amounts Recognized in OCI Not Yet Recognized as Components of Net Periodic Benefit Costs

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)	2022		2021		2022		2021
Net loss/(gain)	$	110	$	52	$	(7)	$	5
Prior service cost/(credit)	1		2		(12)		(19)
Total accumulated OCI	$	111	$	54	$	(19)	$	(14)

Schedule of Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income

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)	2022		2021		2022		2021
Net actuarial loss/(gain)	$	74	$	(72)	$	(11)	$	—
Amortization of net actuarial loss	(3)		(1)		(2)		(1)


Amortization of prior service cost	—		—		8		10
Effect of settlement/curtailment	(14)		(2)		—		—
Total recognized in OCI	$	57	$	(75)	$	(5)	$	9
Net periodic benefit cost/(credit)	18		(27)		(4)		(6)
Net recognized in net periodic pension cost/(credit) and OCI	$	75	$	(102)	$	(9)	$	3

Schedule of Benefit Obligations Significant Components

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


	As of December 31,
	Pension Benefits
(In millions)	2022		2021
Projected benefit obligation	$	1,036	$	1,452
Accumulated benefit obligation	1,022		1,423
Fair value of plan assets	844		1,336

Schedule of Fair Value of Pension Plan Assets by Asset Category and Level within the Fair Value Hierarchy


	Fair Value Measurements as of December 31, 2022
(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	$	—	$	155	$	155
Common/collective trust investment — non-U.S. equity	—		65		65
Common/collective trust investment — non-core assets	—		90		90
Common/collective trust investment — fixed income	—		181		181
Short-term investment fund	22		—		22
Subtotal fair value	$	22	$	491	$	513
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity					33
Common/collective trust investment — fixed income					220
Common/collective trust investment — non-core assets					55
Partnerships/joint ventures					23
Total fair value					$	844


	Fair Value Measurements as of December 31, 2021
(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	$	—	$	221	$	221
Common/collective trust investment — non-U.S. equity	—		69		69
Common/collective trust investment — non-core assets	—		110		110
Common/collective trust investment — fixed income	—		340		340
Short-term investment fund	13		—		13
Subtotal fair value	$	13	$	740	$	753
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity					78
Common/collective trust investment — fixed income					405
Common/collective trust investment — non-core assets					65
Partnerships/joint ventures					35
Total fair value					$	1,336

Schedule of Assumptions Used to Calculate Benefit Expense

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	2022		2021		2022		2021
Discount rate	5.18	%	2.89	%	5.19	%	2.89	%
Interest crediting rate	5.21	%	3.07	%	4.00	%	1.94	%
Rate of compensation increase	3.06	%	3.06	%	—	%	—	%
Health care trend rate	—		—		7.0% grading to 4.4% in 2031		6.8% grading to 4.4% in 2028

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	2022		2021		2020		2022		2021		2020
Discount rate	2.89%/4.71%/5.41%		2.55	%	3.26	%	2.82	%	2.81	%	3.26	%
Interest crediting rate	3.07	%	3.13	%	3.66	%	1.94	%	1.62	%	2.28	%
Expected return on plan assets	4.99	%	5.62	%	5.93	%	—		—		—
Rate of compensation increase	3.06	%	3.06	%	3.00	%	—		—		—
Health care trend rate	—		—		—		6.9% grading to 4.4% in 2028		7.0% grading to 4.4% in 2028		7.5% grading to 4.5% in 2028

Schedule of Target Allocation of Pension Plan Assets

The target allocations of NRG's pension plan assets were as follows for the year ended December 31, 2022:


U.S. equity	21	%
Non-U.S. equity	14	%
Non-core assets	18	%
Fixed Income	47	%

Schedule of Performance Benchmarks

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

Schedule of Expected Benefit Payments

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
2023	$	83	$	7	$	—
2024	81		7		—
2025	79		6		—
2026	77		6		—
2027	76		6		—
2028-2032	361		27		2

Schedule of Benefit Costs and Other Changes Recognized in the Financial Statements Related to its Interest in STP

The Company has recognized the following in its statement of financial position, statement of operations and accumulated OCI related to its 44% interest in STP:


	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2022		2021		2022		2021
Funded status — STPNOC benefit plans	$	(7)	$	(50)	$	(13)	$	(18)
Net periodic benefit cost/(credit)	2		17		(4)		(4)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	(27)		(51)		1		4

Defined Contribution Plan Contributions

The Company's contributions to these plans were as follows:


	Year Ended December 31,
(In millions)	2022		2021		2020
Company contributions to defined contribution plans	$	26	$	25	$	22

Capital Structure (Tables)

12 Months Ended

Dec. 31, 2022

Equity [Abstract]

Changes in NRG's common shares issued and outstanding

The following table reflects the changes in NRG's common shares issued and outstanding for each period presented:


	Common Shares
	Issued	Treasury	Outstanding
Balance as of December 31, 2019	421,890,790	(172,894,601)	248,996,189
Shares issued under ESPP	—	131,469	131,469
Shares issued under LTIPs	1,167,058	—	1,167,058
Share repurchases	—	(6,062,783)	(6,062,783)
Balance as of December 31, 2020	423,057,848	(178,825,915)	244,231,933
Shares issued under ESPP	—	117,392	117,392
Shares issued under LTIPs	489,326	—	489,326
Share repurchases	—	(1,084,752)	(1,084,752)
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
Shares issued under LTIPs	213,208	—	213,208

Balance as of February 15, 2023	424,110,209	(194,335,971)	229,774,238

Summary of shares repurchased

The following table summarizes the shares repurchases made during the years ended December 31, 2020, 2021 and 2022:


	Total number of shares and share equivalents purchased	Average price paid per share and share equivalent		Amounts paid for shares and share equivalents purchased (in millions)


2020 repurchases:
Repurchases	6,062,783			197

Equivalent shares purchased in lieu of tax withholdings on equity compensation issuances(a)	711,248			27
Total Share Repurchases during 2020	6,774,031	$	33.05	$	224
2021 repurchases:
Repurchases(b)	1,084,752			44
Equivalent shares purchased in lieu of tax withholdings on equity compensation issuances(a)	249,013			9
Total Share Repurchases during 2021	1,333,765	$	40.22	$	53
2022 repurchases:
Repurchases	14,685,521			595
Equivalent shares purchased in lieu of tax withholdings on equity compensation issuances(a)	151,241			6
Total Share Repurchases during 2022	14,836,762	$	40.50	$	601

(b)Includes $5 million accrued as of December 31, 2021

Investments Accounted for by the Equity Method and Variable Interest Entities (Tables)

12 Months Ended

Dec. 31, 2022

Equity Method Investments and Joint Ventures [Abstract]

Summary NRG's equity method investments

The following table summarizes NRG's equity method investments as of December 31, 2022:


(In millions, except percentages)
Name:	Economic Interest		Investment Balance
Gladstone	37.5	%	$	128
Ivanpah Master Holdings, LLC(a)	54.5	%	—
Midway-Sunset Cogeneration Company	50.0	%	5
Total equity investments in affiliates			$	133

(a) The equity method of accounting for Ivanpah has been suspended based on losses generated by the project, including the impact of debt service and depreciation

Undistributed earnings by equity investment

The following table summarizes the undistributed earnings from NRG's equity method investments as of December 31, 2022:


	As of December 31,
(In millions)	2022		2021
Undistributed earnings	$	42	$	33

Summary of Financial Information for Consolidated VIEs

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


(In millions)	December 31, 2022		December 31, 2021
Accounts receivable and Other current assets	$	2,108	$	939




Current liabilities	152		78




Net assets	$	1,956	$	861

Income Per Share (Tables)

12 Months Ended

Dec. 31, 2022

Earnings Per Share [Abstract]

Reconciliation of NRG's basic and diluted income per share

The reconciliation of NRG's basic income per share to diluted income per share is shown in the following table:


	Year Ended December 31,
(In millions, except per share amounts)	2022		2021		2020
Basic income per share attributable to NRG Energy, Inc;
Net income attributable to NRG Energy, Inc. common stockholders	$	1,221	$	2,187	$	510



Weighted average number of common shares outstanding-basic	236		245		245
Income per weighted average common share — basic	$	5.17	$	8.93	$	2.08
Diluted income per share attributable to NRG Energy, Inc;
Net income attributable to NRG Energy, Inc. common stockholders	$	1,221	$	2,187	$	510
Weighted average number of common shares outstanding-basic	236		245		245
Incremental shares attributable to the issuance of equity compensation (treasury stock method)	—		—		1
Weighted average number of common shares outstanding-diluted	236		245		246
Income per weighted average common share — diluted	$	5.17	$	8.93	$	2.07

Segment Reporting (Tables)

12 Months Ended

Dec. 31, 2022

Segment Reporting [Abstract]

Segment Reporting


	For the Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenues(a)	$	10,057	$	16,763	$	4,706	$	—	$	17	$	31,543
Operating expenses	8,495		16,031		4,108		86		17		28,737
Depreciation and amortization	310		208		85		31		—		634
Impairment losses	—		206		—		—		—		206
Total operating cost and expenses	8,805		16,445		4,193		117		17		29,577

Gain 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	5		10		3		54		(16)		56

Interest expense	—		(1)		(32)		(400)		16		(417)
Income/(loss) before income taxes	1,265		327		537		(466)		—		1,663
Income tax expense	—		1		57		384		—		442




Net income/(loss)	$	1,265	$	326	$	480	$	(850)	$	—	$	1,221

Balance sheet
Equity investments in affiliates	$	—	$	—	$	133	$	—	$	—	$	133
Capital expenditures	273		7		37		50		—		367
Goodwill	710		723		217		—		—		1,650
Total assets	$	11,475	$	19,526	$	8,139	$	35,780	$	(45,774)	$	29,146


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


	For the Year Ended December 31, 2021
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenues(a)	$	10,295	$	13,025	$	3,659	$	—	$	10	$	26,989
Operating expenses	8,692		10,256		3,467		141		10		22,566
Depreciation and amortization	336		333		88		28		—		785
Impairment losses	—		535		9		—		—		544
Total operating cost and expenses	9,028		11,124		3,564		169		10		23,895

Gain on sale of assets	19		—		17		211		—		247
Operating income	1,286		1,901		112		42		—		3,341
Equity in (losses)/earnings of unconsolidated affiliates	(3)		—		20		—		—		17

Other income, net	8		7		3		59		(14)		63
Loss on debt extinguishment	—		—		—		(77)		—		(77)
Interest expense	(1)		(1)		(28)		(469)		14		(485)
Income/(loss) before income taxes	1,290		1,907		107		(445)		—		2,859
Income tax expense	—		—		19		653		—		672




Net income/(loss)	$	1,290	$	1,907	$	88	$	(1,098)	$	—	$	2,187

Balance sheet
Equity investments in affiliates	$	—	$	—	$	157	$	—	$	—	$	157
Capital expenditures	153		50		21		45		—		269
Goodwill	716		853		226		—		—		1,795
Total assets	$	12,271	$	13,645	$	4,673	$	19,051	$	(26,458)	$	23,182


(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues			$	5					$	(18)					$	3					$	—					$	—					$	(10)


	For the Year Ended December 31, 2020
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenues(a)	$	6,312	$	2,249	$	536	$	—	$	(4)	$	9,093
Operating expenses	5,251		1,755		422		57		(4)		7,481
Depreciation and amortization	233		132		36		34		—		435
Impairment losses	14		—		61		—		—		75
Total operating cost and expenses	5,498		1,887		519		91		(4)		7,991

(Loss)/gain on sale of assets	—		—		(2)		5		—		3
Operating income/(loss)	814		362		15		(86)		—		1,105
Equity in (losses)/earnings of unconsolidated affiliates	(12)		—		29		—		—		17
Impairment losses on investments	(18)		—		—		—		—		(18)
Other income, net	11		7		8		41		—		67
Loss on debt extinguishment	—		(4)		(5)		—		—		(9)
Interest expense	—		(14)		(3)		(384)		—		(401)
Income/(loss) before income taxes	795		351		44		(429)		—		761
Income tax (benefit)/expense	—		(1)		2		250		—		251
Net income/(loss)	$	795	$	352	$	42	$	(679)	$	—	$	510


(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues			$	6					$	(6)					$	4					$	—					$	—					$	4

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2022

Income Tax Disclosure [Abstract]

Income tax provision from continuing operations

The income tax provision consisted of the following amounts:


	Year Ended December 31,
(In millions, except effective income tax rate)	2022			2021			2020
Current
U.S. Federal	$	3		$	—		$	—
State	65			48			22
Foreign	3			3			4
Total — current	71			51			26
Deferred
U.S. Federal	258			569			168
State	59			36			60
Foreign	54			16			(3)
Total — deferred	371			621			225
Total income tax expense	$	442		$	672		$	251
Effective income tax rate	26.6		%	23.5		%	33.0		%

Domestic and foreign components of income/(loss) before income tax (benefit)/expense

The following represented the domestic and foreign components of income before income taxes:


	Year Ended December 31,
(In millions)	2022		2021		2020
U.S.	$	1,436	$	2,759	$	749
Foreign	227		100		12
Total	$	1,663	$	2,859	$	761

Reconciliation of the U.S. federal statutory rate to NRG's effective rate

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)	2022			2021			2020
Income before income taxes	$	1,663		$	2,859		$	761
Tax at federal statutory tax rate	349			600			160
Foreign rate differential	7			(3)			—
State taxes	69			111			18

Permanent differences	17			8			8
Changes in valuation allowance	(3)			(29)			24


Deferred impact of state tax rate changes	14			(10)			2

Recognition of uncertain tax benefits	8			(10)			3
Carbon capture tax credits	(19)			—			—
Return to provision adjustments	—			5			36





Income tax expense	$	442		$	672		$	251
Effective income tax rate	26.6		%	23.5		%	33.0		%

Company's deferred tax assets and liabilities

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)	2022		2021
Deferred tax assets:
Deferred compensation, accrued vacation and other reserves	$	93	$	114
Difference between book and tax basis of property	399		436


Pension and other postretirement benefits	62		65
Equity compensation	8		7
Allowance for credit losses	33		168

U.S. Federal net operating loss carryforwards	1,717		1,773
Foreign net operating loss carryforwards	104		112
State net operating loss carryforwards	315		328

Federal and state tax credit carryforwards	393		384
Federal benefit on state uncertain tax positions	5		3

Interest disallowance carryforward per §163(j) of the Tax Act	65		6
Inventory obsolescence	10		9
U.S. capital loss	15		—
Other	22		15

Total deferred tax assets	3,241		3,420
Deferred tax liabilities:
Emissions allowances	19		20


Derivatives	874		591
Goodwill	26		40
Intangibles amortization (excluding goodwill)	269		363
Equity method investments	82		62

Convertible Debt	—		14


Total deferred tax liabilities	1,270		1,090
Total deferred tax assets less deferred tax liabilities	1,971		2,330
Valuation allowance	(224)		(248)

Total net deferred tax assets, net of valuation allowance	$	1,747	$	2,082

Summary of NRG's net deferred tax position

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


	As of December 31,
(In millions)	2022		2021
Deferred tax asset	$	1,881	$	2,155

Deferred tax liability	(134)		(73)
Net deferred tax asset	$	1,747	$	2,082

Reconciliation of total amounts of uncertain tax benefits

The following table summarizes uncertain tax benefits activity:


	As of December 31,
(In millions)	2022		2021
Balance as of January 1	$	13	$	15
Increase due to current year positions	9		4
Increase due to acquired balance from Direct Energy	—		9

Settlements, payments and statute closure	—		(15)
Uncertain tax benefits as of December 31	$	22	$	13

Stock-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2022

Share-Based Payment Arrangement, Noncash Expense [Abstract]

Summary of Company's non-vested RSU awards and changes during the year

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, 2021	669,952	$	38.69
Granted	530,565	41.26
Forfeited	(43,601)	41.09
Vested	(299,999)	38.36

Non-vested at December 31, 2022	856,917	40.25

Summary of Company's DSU awards and non-vested PSU Awards changes during the year

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, 2021	384,128	$	26.11
Granted	52,865	45.49

Converted to Common Stock	(18,979)	39.27

Outstanding at December 31, 2022	418,014	27.63

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, 2021	730,505	$	47.40
Granted	291,852	57.41
Forfeited	(54,392)	46.68
Vested	(172,630)	45.77
Non-vested at December 31, 2022	795,335	50.23

Schedule of Assumptions used in Fair Value Model

Significant assumptions used in the fair value model with respect to the Company's RPSUs are summarized below:


	2022		2021(a)		2020
	RPSUs		RPSUs		RPSUs
Expected volatility	37.54	%	34.05	%	30.15	%
Expected term (in years)	3		3		3
Risk free rate	0.97	%	0.17	%	1.58	%

(a)Assumptions pertain to the main award granted in January 2021. Additional 60,815 RPSUs were granted in September 2021 with a risk free rate of 0.42% and expected volatility of 37.38%

Summary of NRG's total compensation expense recognized and total non-vested compensation costs not yet recognized and the period over which this expense is expected to be recognized


							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	2022		2021		2020		2022		2022

RSUs	$	15	$	9	$	9	$	17	1.75
DSUs	2		2		2		—		0.00

RPSUs	11		9		10		13		1.16
PRSUs(a)	6		7		6		7		1.45
Total	$	34	$	27	$	27	$	37
Tax detriment/(benefit) recognized	$	3	$	2	$	(9)

Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2022

Summary of NRG's material related-party transactions with affiliates

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


	Year Ended December 31,
(In millions)	2022		2021		2020
Revenues from Related Parties Included in Revenues
Gladstone	$	4	$	4	$	4
Ivanpah(a)	42		39		43
Midway-Sunset	6		6		5
Total	$	52	$	49	$	52

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

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2022

Commitments and Contingencies Disclosure [Abstract]

Commitments under coal, gas and transportation contractual agreements

As of December 31, 2022, the Company's minimum commitments under such outstanding agreements are estimated as follows:


Period	(In millions)
2023	$	110
2024	71
2025	83
2026	54
2027	78
Thereafter	56
Total(a)	$	452

(a)Actual fuel and transportation purchases are significantly higher than these estimated minimum unconditional long-term firm commitments with remaining term in excess of one year

Minimum purchase commitment obligations under purchased power agreements

These contracts are not included in the consolidated balance sheet as of December 31, 2022. Minimum purchase commitment obligations are as follows as of December 31, 2022:


Period	(In millions)
2023	$	908
2024	1,050
2025	662
2026	396
2027	296
Thereafter	987
Total(a)	$	4,299

Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2022

Supplemental Cash Flow Information [Abstract]

Details of supplemental disclosures of cash flow and non-cash investing and financing information


	Year Ended December 31,
(In millions)	2022		2021		2020
Cash and cash equivalents	$	430	$	250	$	3,905
Funds deposited by counterparties	1,708		845		19
Restricted cash	40		15		6
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$	2,178	$	1,110	$	3,930

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


	Year Ended December 31,
(In millions)	2022		2021		2020
Interest paid, net of amount capitalized	$	383	$	433	$	340
Income taxes paid, net of refunds	66		32		24
Non-cash investing activities:
Decreases to fixed assets for accrued capital expenditures	(68)		(16)		(6)

Guarantees (Tables)

12 Months Ended

Dec. 31, 2022

Guarantees [Abstract]

Summary of maximum potential exposure that can be estimated by NRG's guarantees, indemnity, and other contingent 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)	2022
Guarantees	Under 1 Year		1-3 Years		3-5 Years		Over 5 Years		Total		2021 Total
Letters of credit and surety bonds	$	5,211	$	—	$	—	$	—	$	5,211	$	4,095
Asset sales guarantee obligations	270		25		34		80		409		414
Other guarantees	—		—		—		15		15		93
Total guarantees	$	5,481	$	25	$	34	$	95	$	5,635	$	4,602

Jointly Owned Plants (Tables)

12 Months Ended

Dec. 31, 2022

Jointly Owned Plants Disclosure [Abstract]

Summary of NRG's proportionate ownership interest in the company's jointly-owned facilities

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


(In millions unless otherwise stated)
As of December 31, 2022	Ownership Interest		Property, Plant & Equipment		Accumulated Depreciation		Construction in Progress
South Texas Project Units 1 and 2, Bay City, TX	44.00	%	$	478	$	(235)	$	7
Cedar Bayou Unit 4, Baytown, TX	50.00	%	229		(118)		7

Nature of Business (Details) customer in Millions	12 Months Ended
Nature of Business (Details) customer in Millions	Dec. 31, 2022 customer MW
Business Acquisition [Line Items]
Generation capacity (in MW) \| MW	16
Home
Business Acquisition [Line Items]
Customers served \| customer	5.4

Summary of Significant Accounting Policies - Additional (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Securitization Proceeds [Abstract]
Proceeds from ERCOT	$ 689
Funds Deposited by Counterparties
Number of months beyond which company can not predict the holding of collateral (in months)		12 months
Loss Contingency [Abstract]
Insurance settlement		$ 81
Finite-Lived Intangible Assets, Net [Abstract]
Intangible assets, accumulated amortization		2,112	$ 1,636
Gross Receipts and Sales Taxes
Gross receipts taxes		218	184	$ 107
Purchased Energy and Other Cost of Sales for Customer Operations
Transmission and distribution charges not yet billed		202	189	98
Foreign Currency Translation and Transaction Gains and Losses
Foreign currency transaction losses		(7)
Cumulative translation adjustment		55	(8)	(2)
Marketing and Advertising Costs
Advertising expense		$ 82	$ 109	$ 74
South Texas Project
Property, Plant and Equipment
Ownership Interest (as a percent)		44.00%

Summary of Significant Accounting Policies - Activity in the Allowance for Credit Losses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	$ 683	$ 67	$ 43
Acquired balance from Direct Energy	0	112	0
Provision for credit losses	11	698	108
Write-offs	(593)	(224)	(101)
Recoveries collected	32	30	17
Ending balance	133	683	$ 67
Provision for credit losses increase due finance hedge risk	$ (70)	$ 403

Summary of Significant Accounting Policies - Credit Losses Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Summary of Significant Accounting Policies [Line Items]
Provision (income) for credit losses	$ 11	$ 698	$ 108
Winter Storm Uri
Summary of Significant Accounting Policies [Line Items]
Provision (income) for credit losses	$ (126)	$ 596

Summary of Significant Accounting Policies - Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Cash and cash equivalents	$ 430	$ 250	$ 3,905
Funds deposited by counterparties	1,708	845	19
Restricted cash	40	15	6
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$ 2,178	$ 1,110	$ 3,930	$ 385

Summary of Significant Accounting Policies - Recent Accounting Developments (Details) - USD ($) $ in Millions	Dec. 31, 2022	Jan. 01, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Adjustment for adoption of new accounting guidance	$ 3,828		$ 3,600	$ 1,680	$ 1,658
Deferred tax liabilities	(1,270)		(1,090)
Cumulative Effect, Period of Adoption, Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Adjustment for adoption of new accounting guidance			(43)
Debt discount		$ 57
Deferred tax liabilities		14
Additional Paid-In Capital
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Adjustment for adoption of new accounting guidance	8,457		8,531	8,517	8,501
Additional Paid-In Capital \| Cumulative Effect, Period of Adoption, Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Adjustment for adoption of new accounting guidance		(100)	(100)
Retained Earnings
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Adjustment for adoption of new accounting guidance	$ 1,408		464	$ (1,403)	$ (1,616)
Retained Earnings \| Cumulative Effect, Period of Adoption, Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Adjustment for adoption of new accounting guidance		$ 57	$ 57

- Definition

Amount of stockholders' equity (deficit), net of receivables from officers, directors, owners, and affiliates of the entity, attributable to both the parent and noncontrolling interests. Amount excludes temporary equity. Alternate caption for the concept is permanent equity.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 11: http://www.xbrl.org/2009/role/commonPracticeRef
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+ Details

Revenue Recognition - Capacity Revenue (Details) $ in Millions	Dec. 31, 2022 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue from Contract with Customer [Abstract]
Estimated future fixed fee performance obligation	$ 77
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue from Contract with Customer [Abstract]
Estimated future fixed fee performance obligation	$ 23
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue from Contract with Customer [Abstract]
Estimated future fixed fee performance obligation	$ 2
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, period	1 year

Revenue Recognition - Disaggregated Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	$ 31,488	$ 26,777	$ 8,690
Mark-to-market for economic hedging activities	1,248	2,716	(119)
Revenues	31,543	26,989	9,093
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	35	(22)	18
Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	110
Retail Revenue \| Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	10,761	9,549	6,331
Retail Revenue \| Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	18,961	14,012	1,129
Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	29,722	23,561	7,460
Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	1,250	1,215	539
Derivative revenue	(8)	136	105
Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	272	775	680
Derivative revenue	33	149	156
Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	(83)	(164)	95
Less: Realized and unrealized ASC 815 revenue	20	234	385
Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	421	1,632	319
Contract amortization	(39)	(30)	0
Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	31,543	26,989	9,093
Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	(32)	113	29
Corporate/Eliminations
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(15)	(6)	(7)
Revenues	17	10	(4)
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	1	0	0
Corporate/Eliminations \| Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	0
Corporate/Eliminations \| Retail Revenue \| Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(1)	(1)	(2)
Corporate/Eliminations \| Retail Revenue \| Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0
Corporate/Eliminations \| Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(1)	(1)	(2)
Corporate/Eliminations \| Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	32	7	(1)
Derivative revenue	31	3	(5)
Corporate/Eliminations \| Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	(1)
Derivative revenue	0	0	0
Corporate/Eliminations \| Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	1	13	8
Less: Realized and unrealized ASC 815 revenue	31	16	3
Corporate/Eliminations \| Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(15)	(9)	(8)
Contract amortization	0	0	0
Corporate/Eliminations \| Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	17	10	(4)
Corporate/Eliminations \| Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	(1)	0	0
Texas \| Operating Segments
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	10,059	10,165	6,282
Revenues	10,057	10,295	6,312
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	0	0	0
Texas \| Operating Segments \| Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	0
Texas \| Operating Segments \| Retail Revenue \| Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	6,388	5,659	5,020
Texas \| Operating Segments \| Retail Revenue \| Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	3,229	2,745	1,034
Texas \| Operating Segments \| Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	9,617	8,404	6,054
Texas \| Operating Segments \| Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	111	329	24
Derivative revenue	0	0	0
Texas \| Operating Segments \| Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0
Derivative revenue	0	0	0
Texas \| Operating Segments \| Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	2	(3)	2
Less: Realized and unrealized ASC 815 revenue	(2)	130	30
Texas \| Operating Segments \| Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	327	1,565	232
Contract amortization	0	0	0
Texas \| Operating Segments \| Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	10,057	10,295	6,312
Texas \| Operating Segments \| Other ancillary revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer		1,300
Texas \| Operating Segments \| Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	(4)	133	28
Texas \| Corporate/Eliminations
Disaggregation of Revenue [Line Items]
Revenues	(4)	(5)	(6)
East \| Operating Segments
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	16,686	12,866	1,934
Revenues	16,763	13,025	2,249
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	(7)	(25)	1
East \| Operating Segments \| Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	110
East \| Operating Segments \| Retail Revenue \| Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	2,088	1,832	1,210
East \| Operating Segments \| Retail Revenue \| Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	13,768	10,030	95
East \| Operating Segments \| Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	15,856	11,862	1,305
East \| Operating Segments \| Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	641	508	183
Derivative revenue	(31)	131	67
East \| Operating Segments \| Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	232	718	620
Derivative revenue	33	149	156
East \| Operating Segments \| Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	(30)	(88)	88
Less: Realized and unrealized ASC 815 revenue	84	184	314
East \| Operating Segments \| Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	104	51	53
Contract amortization	(40)	(26)	0
East \| Operating Segments \| Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	16,763	13,025	2,249
East \| Operating Segments \| Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	2	(8)	3
East \| Corporate/Eliminations
Disaggregation of Revenue [Line Items]
Revenues	26	18	6
West/Services/Other \| Operating Segments
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	4,758	3,752	481
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	41	3	17
West/Services/Other \| Operating Segments \| Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	0
West/Services/Other \| Operating Segments \| Retail Revenue \| Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	2,286	2,059	103
West/Services/Other \| Operating Segments \| Retail Revenue \| Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	1,964	1,237	0
West/Services/Other \| Operating Segments \| Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	4,250	3,296	103
West/Services/Other \| Operating Segments \| Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	466	371	333
Derivative revenue	(8)	2	43
West/Services/Other \| Operating Segments \| Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	40	57	61
Derivative revenue	0	0	0
West/Services/Other \| Operating Segments \| Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	(56)	(86)	(3)
Less: Realized and unrealized ASC 815 revenue	(93)	(96)	38
West/Services/Other \| Operating Segments \| Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	5	25	42
Contract amortization	1	(4)	0
West/Services/Other \| Operating Segments \| Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	4,706	3,659	536
West/Services/Other \| Operating Segments \| Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	$ (29)	$ (12)	$ (2)

Revenue Recognition - Contract Balances (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Schedule Of Contract Assets And Liabilities [Line Items]
Deferred customer acquisition costs	$ 126	$ 133
Accounts receivable, net	4,773	3,245
Unbilled revenues (included within Accounts receivable, net - Contracts with customers)	1,952	1,574
Deferred revenue	186	227
Deferred revenue from contract with customers	175	224
Revenue recognized	184	23
Accounts receivable, net - Contracts with customers
Schedule Of Contract Assets And Liabilities [Line Items]
Accounts receivable, net	4,704	3,057
Accounts receivable, net - Accounted for under topics other than ASC 606
Schedule Of Contract Assets And Liabilities [Line Items]
Accounts receivable, net	64	182
Accounts receivable, net - Affiliate
Schedule Of Contract Assets And Liabilities [Line Items]
Accounts receivable, net	$ 5	$ 6

Acquisitions and Dispositions - Acquisitions (Details) $ / shares in Units, $ in Millions			3 Months Ended	12 Months Ended
	Jan. 05, 2021 USD ($) customer state province	Sep. 29, 2020 USD ($)	Mar. 31, 2023 USD ($) $ / shares	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 06, 2022 USD ($)
Business Acquisition [Line Items]
Operating lease liability				$ 263
Joliet facility
Business Acquisition [Line Items]
Lease expense							$ 14
Operating lease liability		$ 148
Powerton Facility And Units 7 And 8 Of The Joliet Facility
Business Acquisition [Line Items]
Purchase of assets		$ 260
Canada
Business Acquisition [Line Items]
Provinces in which entity operates \| province	8
Senior Secured Term Loan \| Bridge Loan facility
Business Acquisition [Line Items]
Term of facility				364 days
Revolving credit facility								$ 2,100
Vivint Smart Home Inc.
Business Acquisition [Line Items]
Acquisition costs				$ 17
Vivint Smart Home Inc. \| Subsequent Event \| Scenario, Forecast
Business Acquisition [Line Items]
Acquisition, share price (in usd per share) \| $ / shares			$ 12
Cash paid to acquire business			$ 2,800
Vivint Smart Home Inc. \| Subsequent Event \| Scenario, Forecast \| Revolving Credit Facility
Business Acquisition [Line Items]
Increase in existing borrowing commitments			$ 600
Direct Energy
Business Acquisition [Line Items]
Customers \| customer	3,000,000
Acquisition costs					$ 25	$ 17
Purchase price	$ 3,625
Purchase price adjustment	99
Adjusted purchase price	$ 3,724
Direct Energy \| U.S.
Business Acquisition [Line Items]
Number of states in which the entity operates \| state	50

Acquisitions and Dispositions - Direct Energy Purchase Price Allocation (Details) - USD ($) $ in Millions		12 Months Ended
	Jan. 05, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Other Assets
Goodwill		$ 1,650	$ 1,795	$ 579
Texas
Other Assets
Goodwill		710	716	289
East
Other Assets
Goodwill		$ 723	$ 853	$ 240
Customer Relationships
Other Liabilities
Weighted average useful life, years		6 years	12 years
Direct Energy
Current Assets
Cash and cash equivalents			$ 152
Funds deposited by counterparties			21
Restricted cash			9
Accounts receivable, net			1,802
Inventory			106
Derivative instruments			1,014
Cash collateral paid in support of energy risk management activities			233
Prepayments and other current assets			173
Total current assets			3,510
Property, plant and equipment, net			151
Other Assets
Goodwill			1,250
Intangible assets			2,321
Derivative instruments			531
Other non-current assets			31
Total other assets			4,133
Total Assets			7,794
Current Liabilities
Accounts payable			1,116
Derivative instruments			1,266
Cash collateral received in support of energy risk management activities			21
Accrued expenses and other current liabilities			670
Total current liabilities			3,073
Other Liabilities
Derivative instruments			562
Deferred income taxes			320
Other non-current liabilities			115
Total other liabilities			997
Total Liabilities			4,070
Direct Energy Purchase Price			3,724
Goodwill, expected to be tax deductible			322
Direct Energy \| Texas
Other Assets
Goodwill			427
Direct Energy \| East
Other Assets
Goodwill			648
Direct Energy \| West/Services/Other
Other Assets
Goodwill			175
Direct Energy \| Customer Relationships
Other Assets
Intangible assets			1,277
Other Liabilities
Weighted average useful life, years	12 years
Direct Energy \| Customer and Supply Contracts
Other Assets
Intangible assets			610
Other Liabilities
Weighted average useful life, years	12 years
Direct Energy \| Trade Names
Other Assets
Intangible assets			310
Other Liabilities
Weighted average useful life, years	12 years
Direct Energy \| Renewables Energy Certificates
Other Assets
Intangible assets			$ 124
Other Liabilities
Weighted average useful life, years	12 years

Acquisitions and Dispositions - Dispositions (Details) $ in Millions						3 Months Ended	12 Months Ended
	Jan. 06, 2023 USD ($)	Jun. 01, 2022 USD ($)	Dec. 01, 2021 USD ($) MW	Feb. 03, 2021 USD ($)	Nov. 13, 2020 USD ($)	Sep. 30, 2020 USD ($)	Dec. 31, 2022 USD ($) MW	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Generation capacity (in MW) \| MW							16
Loss on debt extinguishment							$ 0	$ 77	$ 9
Watson Facility
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage		49.00%
Proceeds from sale of investment		$ 59
Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations \| Agua Caliente Solar Project
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration				$ 202
Percentage of ownership sold				35.00%
Gain on sale				$ 17
Cash disposed				$ 7
Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations \| Home Solar
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain (loss) on sale of business					$ (2)
Proceeds from sale					66
Debt extinguished					27
Loss on debt extinguishment					$ 5
Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations \| Indemnification Agreement
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Guarantee (up to)			$ 39
East \| Disposal Group, Disposed of by Sale, Not Discontinued Operations \| Subsequent Event
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale	$ 212
Transaction fees on disposal	$ 3
West/Services/Other \| Watson Facility
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on sale of investment		$ 46
West/Services/Other \| Held-for-sale \| Home Solar
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment loss to adjust the carrying amount of assets and liabilities						$ 29
East/West Other \| Arthur Kill Plant
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Generation capacity (in MW) \| MW			866
East/West Other \| Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Generation capacity (in MW) \| MW			4,850
Consideration			$ 760
Working capital adjustments			140
Proceeds from sale of, net of working capital adjustments			620
Gain (loss) on sale of business			$ 207

Fair Value of Financial Instruments - Estimated Carrying Amounts of Fair Value of Financial Instruments not Carried at Fair Value (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Liabilities
Long-term debt	$ 8,100	$ 8,100
Carrying Amount
Liabilities
Long-term debt	8,098	8,040
Carrying Amount \| Senior Debt Obligations
Liabilities
Long-term debt	575	518
Carrying Amount \| Other Debt Obligations
Liabilities
Long-term debt	7,523	7,522
Fair Value
Liabilities
Long-term debt	7,008	8,327
Fair Value \| Senior Debt Obligations
Liabilities
Long-term debt	576	677
Fair Value \| Other Debt Obligations
Liabilities
Long-term debt	$ 6,432	$ 7,650

- Definition

Amount, excluding unamortized premium (discount) and debt issuance cost, of long-term debt. Excludes lease obligation.

+ References + Details

Fair Value of Financial Instruments - Assets and Liabilities Measured and Recorded at Fair Value (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments in securities (classified within other current and non-current assets)	$ 19	$ 32
Other trust fund investments (classified within other non-current assets):
Other trust fund investments	1	1
Measured using net asset value practical expedient:
Total assets	12,858	8,188
Derivative liabilities:
Total liabilities	8,441	4,799
Foreign exchange contract
Derivative assets:
Derivative Assets	18	1
Derivative liabilities:
Commodity contracts	2	1
Commodity contracts
Derivative assets:
Derivative Assets	11,976	7,139
Derivative liabilities:
Commodity contracts	8,439	4,798
Cash and cash equivalents
Nuclear trust fund investments:
Nuclear trust fund investments	15	33
U.S. government and federal agency obligations
Nuclear trust fund investments:
Nuclear trust fund investments	86	112
Federal agency mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments	101	100
Commercial mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments	35	44
Corporate debt securities
Nuclear trust fund investments:
Nuclear trust fund investments	114	122
Equity securities
Nuclear trust fund investments:
Nuclear trust fund investments	403	494
Foreign government fixed income securities
Nuclear trust fund investments:
Nuclear trust fund investments	1	4
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments in securities (classified within other current and non-current assets)	0	15
Other trust fund investments (classified within other non-current assets):
Other trust fund investments	1	1
Measured using net asset value practical expedient:
Total assets	2,432	1,635
Derivative liabilities:
Total liabilities	1,244	626
Level 1 \| Foreign exchange contract
Derivative assets:
Derivative Assets	0	0
Derivative liabilities:
Commodity contracts	0	0
Level 1 \| Commodity contracts
Derivative assets:
Derivative Assets	1,929	981
Derivative liabilities:
Commodity contracts	1,244	626
Level 1 \| Cash and cash equivalents
Nuclear trust fund investments:
Nuclear trust fund investments	15	33
Level 1 \| U.S. government and federal agency obligations
Nuclear trust fund investments:
Nuclear trust fund investments	84	111
Level 1 \| Federal agency mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 1 \| Commercial mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 1 \| Corporate debt securities
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 1 \| Equity securities
Nuclear trust fund investments:
Nuclear trust fund investments	403	494
Level 1 \| Foreign government fixed income securities
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments in securities (classified within other current and non-current assets)	19	17
Other trust fund investments (classified within other non-current assets):
Other trust fund investments	0	0
Measured using net asset value practical expedient:
Total assets	9,086	5,990
Derivative liabilities:
Total liabilities	6,451	4,009
Level 2 \| Foreign exchange contract
Derivative assets:
Derivative Assets	18	1
Derivative liabilities:
Commodity contracts	2	1
Level 2 \| Commodity contracts
Derivative assets:
Derivative Assets	8,796	5,701
Derivative liabilities:
Commodity contracts	6,449	4,008
Level 2 \| Cash and cash equivalents
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 2 \| U.S. government and federal agency obligations
Nuclear trust fund investments:
Nuclear trust fund investments	2	1
Level 2 \| Federal agency mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments	101	100
Level 2 \| Commercial mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments	35	44
Level 2 \| Corporate debt securities
Nuclear trust fund investments:
Nuclear trust fund investments	114	122
Level 2 \| Equity securities
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 2 \| Foreign government fixed income securities
Nuclear trust fund investments:
Nuclear trust fund investments	1	4
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments in securities (classified within other current and non-current assets)	0	0
Other trust fund investments (classified within other non-current assets):
Other trust fund investments	0	0
Measured using net asset value practical expedient:
Total assets	1,251	457
Derivative liabilities:
Total liabilities	746	164
Level 3 \| Foreign exchange contract
Derivative assets:
Derivative Assets	0	0
Derivative liabilities:
Commodity contracts	0	0
Level 3 \| Commodity contracts
Derivative assets:
Derivative Assets	1,251	457
Derivative liabilities:
Commodity contracts	746	164
Level 3 \| Cash and cash equivalents
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 3 \| U.S. government and federal agency obligations
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 3 \| Federal agency mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 3 \| Commercial mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 3 \| Corporate debt securities
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 3 \| Equity securities
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Level 3 \| Foreign government fixed income securities
Nuclear trust fund investments:
Nuclear trust fund investments	0	0
Net Asset Value \| Equity securities
Measured using net asset value practical expedient:
Equity securities	6	7
Net Asset Value \| Equity securities - nuclear trust fund investments
Measured using net asset value practical expedient:
Equity securities	$ 83	$ 99

Fair Value of Financial Instruments - Reconciliation of Level 3 Financial Instruments (Details) - Level 3 - Derivative - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 293	$ (16)
Contracts added from Direct Energy acquisition	0	(15)
Total gains realized/unrealized included in earnings	53	145
Purchases	(110)	93
Transfers into Level 3	264	71
Transfers out of Level 3	5	15
Ending balance	505	293
Gains 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	$ 204	$ 120

Fair Value of Financial Instruments - Derivative Fair Value Measurements Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Total derivative assets valued with prices provided by models and other valuation techniques percentage	10.00%
Total derivative liabilities valued with prices provided by models and other valuation techniques, percentage	9.00%
Change in credit reserve	$ 9	$ 11

Fair Value of Financial Instruments - Significant Unobservable Inputs Used in Fair Value of Level 3 Positions (Details) $ in Millions	Dec. 31, 2022 USD ($) $ / MWh	Dec. 31, 2021 USD ($) $ / MWh
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Cash collateral paid in support of energy risk management activities	$ 260	$ 291
Cash collateral received in support of energy risk management activities	1,708	845
Commodity contracts
Assets
Derivative Assets	11,976	7,139
Liabilities
Derivative Liabilities	8,439	4,798
Commodity contracts \| Level 3
Assets
Derivative Assets	1,251	457
Liabilities
Derivative Liabilities	746	164
Commodity contracts \| Natural Gas Contracts \| Level 3
Assets
Derivative Assets		16
Liabilities
Derivative Liabilities		$ 1
Commodity contracts \| Natural Gas Contracts \| Level 3 \| Low
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Forward Market Price (USD per MWh) \| $ / MWh		3
Commodity contracts \| Natural Gas Contracts \| Level 3 \| High
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Forward Market Price (USD per MWh) \| $ / MWh		40
Commodity contracts \| Natural Gas Contracts \| Level 3 \| Weighted Average
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Forward Market Price (USD per MWh) \| $ / MWh		15
Commodity contracts \| Fair Value, Measurements, Recurring \| Level 3
Assets
Derivative Assets	1,251	$ 457
Liabilities
Derivative Liabilities	746	164
Commodity contracts \| Fair Value, Measurements, Recurring \| Natural Gas Contracts \| Level 3
Assets
Derivative Assets	340
Liabilities
Derivative Liabilities	$ 448
Commodity contracts \| Fair Value, Measurements, Recurring \| Natural Gas Contracts \| Level 3 \| Low
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Forward Market Price (USD per MWh) \| $ / MWh	2
Commodity contracts \| Fair Value, Measurements, Recurring \| Natural Gas Contracts \| Level 3 \| High
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Forward Market Price (USD per MWh) \| $ / MWh	48
Commodity contracts \| Fair Value, Measurements, Recurring \| Natural Gas Contracts \| Level 3 \| Weighted Average
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Forward Market Price (USD per MWh) \| $ / MWh	6
Commodity contracts \| Fair Value, Measurements, Recurring \| Power Contracts \| Level 3
Assets
Derivative Assets	$ 843	392
Liabilities
Derivative Liabilities	$ 216	$ 121
Commodity contracts \| Fair Value, Measurements, Recurring \| Power Contracts \| Level 3 \| Low
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Forward Market Price (USD per MWh) \| $ / MWh	3	3
Commodity contracts \| Fair Value, Measurements, Recurring \| Power Contracts \| Level 3 \| High
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Forward Market Price (USD per MWh) \| $ / MWh	431	212
Commodity contracts \| Fair Value, Measurements, Recurring \| Power Contracts \| Level 3 \| Weighted Average
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Forward Market Price (USD per MWh) \| $ / MWh	48	35
Commodity contracts \| Fair Value, Measurements, Recurring \| FTRs \| Level 3
Assets
Derivative Assets	$ 68	$ 49
Liabilities
Derivative Liabilities	$ 82	$ 42
Commodity contracts \| Fair Value, Measurements, Recurring \| FTRs \| Level 3 \| Low
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Auction Prices (USD per MWh) \| $ / MWh	(32)	(122)
Commodity contracts \| Fair Value, Measurements, Recurring \| FTRs \| Level 3 \| High
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Auction Prices (USD per MWh) \| $ / MWh	610	43
Commodity contracts \| Fair Value, Measurements, Recurring \| FTRs \| Level 3 \| Weighted Average
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Auction Prices (USD per MWh) \| $ / MWh	0	0

Fair Value of Financial Instruments - Counterparty Credit Risk (Details) - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Dec. 31, 2022	Feb. 28, 2021	Dec. 31, 2022
Derivative Fair Value Meaurements and Concentration of Credit Risk
Counterparty credit exposure, excluding credit risk exposure under certain long term agreements	$ 2,700		$ 2,700
Counterparty credit exposure, collateral held (cash and letters of credit) against positions	1,000		1,000
Counterparty credit exposure, net	$ 1,700		$ 1,700
Company's exposure before collateral expected to roll off (as a percent)			80.00%
Net exposure (as a percent)	100.00%		100.00%
Counterparty credit risk exposure to certain counterparties, threshold (as a percent)			10.00%
Proceeds from loss mitigation efforts related to hedging transaction	$ 70
Estimated counterparty credit risk exposure under certain long term agreements, including California tolling agreements, South Central load obligations and solar power purchase agreements for the next 5 years			$ 1,100
Period of estimated counterparty credit risk exposure under certain long term agreements, including California tolling agreements, South Central load obligations and solar power purchase agreements (in years)			5 years
Designated as Hedging Instrument
Derivative Fair Value Meaurements and Concentration of Credit Risk
Counterparty nonperformance exposure		$ 403
Investment grade
Derivative Fair Value Meaurements and Concentration of Credit Risk
Net exposure (as a percent)	65.00%		65.00%
Non-Investment grade/Non-Rated
Derivative Fair Value Meaurements and Concentration of Credit Risk
Net exposure (as a percent)	35.00%		35.00%
Utilities, energy merchants, marketers and other
Derivative Fair Value Meaurements and Concentration of Credit Risk
Net exposure (as a percent)	62.00%		62.00%
Financial Institutions
Derivative Fair Value Meaurements and Concentration of Credit Risk
Net exposure (as a percent)	38.00%		38.00%

Fair Value of Financial Instruments - Retail Customer Credit Risk (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Derivative Fair Value Meaurements and Concentration of Credit Risk
Provision for credit losses (income recognized) due to loss mitigation efforts	$ 11	$ 698	$ 108
Winter Storm Uri
Derivative Fair Value Meaurements and Concentration of Credit Risk
Provision for credit losses (income recognized) due to loss mitigation efforts	$ (126)	$ 596

Accounting for Derivative Instruments and Hedging Activities - Net Notional Volume Buy/Sell of Open Derivative Transactions (Details) certificate in Millions, bbl in Millions, T in Millions, MWh in Millions, MMBTU in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) MMBTU MWh certificate T bbl	Dec. 31, 2021 USD ($) MMBTU MWh certificate T bbl
Long \| Emissions
Derivative [Line Items]
Derivative, nonmonetary notional amount, mass (ton)	1	1
Long \| Renewables Energy Certificates
Derivative [Line Items]
Derivative, non-monetary notional amount (in shares) \| certificate	15	13
Long \| Coal
Derivative [Line Items]
Derivative, nonmonetary notional amount, mass (ton)	11	19
Long \| Oil
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume (in barrels) \| bbl	1	1
Long \| Power
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure in (millions of btu) and (megawatt hours) \| MWh	192	185
Long \| Foreign Exchange
Derivative [Line Items]
Derivative, notional amount (usd) \| $	$ 569	$ 279
Short \| Natural Gas
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure in (millions of btu) and (megawatt hours) \| MMBTU	422	813

Accounting for Derivative Instruments and Hedging Activities - Fair Value Within the Derivative Instrument Valuation (Details) - Not Designated as Hedging Instrument - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Derivative [Line Items]
Derivative Assets	$ 11,994	$ 7,140
Derivative Liabilities	8,441	4,799
Foreign exchange contracts - current
Derivative [Line Items]
Derivative Assets	11	0
Derivative Liabilities	1	1
Foreign exchange contracts - long-term
Derivative [Line Items]
Derivative Assets	7	1
Derivative Liabilities	1	0
Commodity contracts- current
Derivative [Line Items]
Derivative Assets	7,875	4,613
Derivative Liabilities	6,194	3,386
Commodity contracts- long-term
Derivative [Line Items]
Derivative Assets	4,101	2,526
Derivative Liabilities	$ 2,245	$ 1,412

Accounting for Derivative Instruments and Hedging Activities - Offsetting of Derivatives by Counterparty Master Agreement level and Collateral Received (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid
Gross Amounts of Recognized Assets / Liabilities	$ 3,553	$ 2,341
Derivative Instruments	0	0
Cash Collateral (Held) / Posted	(1,639)	(814)
Net Amount	1,914	1,527
Foreign exchange contract
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid
Derivative Assets	18	1
Derivative Instruments	(2)	(1)
Cash Collateral (Held)/Posted	0	0
Net Amount	16	0
Derivative liabilities	(2)	(1)
Derivative Instruments	2	1
Cash Collateral (Held)/Posted	0	0
Net Amount	0	0
Gross Amounts of Recognized Assets / Liabilities	16	0
Derivative Instruments	0	0
Cash Collateral (Held) / Posted	0	0
Net Amount	16	0
Commodity contracts
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid
Derivative Assets	11,976	7,139
Derivative Instruments	(7,897)	(4,440)
Cash Collateral (Held)/Posted	(1,659)	(831)
Net Amount	2,420	1,868
Derivative liabilities	(8,439)	(4,798)
Derivative Instruments	7,897	4,440
Cash Collateral (Held)/Posted	20	17
Net Amount	(522)	(341)
Gross Amounts of Recognized Assets / Liabilities	3,537	2,341
Derivative Instruments	0	0
Cash Collateral (Held) / Posted	(1,639)	(814)
Net Amount	$ 1,898	$ 1,527

Accounting for Derivative Instruments and Hedging Activities - Pre-tax Effects of Economic Hedges not Designated as Cash Flow Hedges (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Unrealized Mark To Market Results [Abstract]
Reversal of previously recognized unrealized (gains) on settled positions related to economic hedges	$ (1,232)	$ (41)	$ (55)
Reversal of acquired loss positions related to economic hedges	2	256	4
Total unrealized mark-to-market gains/(losses) for economic hedging activities	1,248	2,716	(119)
Reversal of previously recognized unrealized losses/(gains) on settled positions related to trading activity	13	(18)	(20)
Reversal of Acquired (gain) Positions Related to Trading Activity	0	(1)	0
Net unrealized (losses)/gains on open positions related to trading activity	(17)	(13)	15
Total unrealized mark-to-market (losses) for trading activity	(4)	(32)	(5)
Total unrealized gains/(losses)	1,244	2,684	(124)
Credit Risk Related Contingent Features [Abstract]
Collateral required contracts with credit rating contingent features in a net liability position	195
Additional collateral required	30
Adequate Assurance Clauses
Credit Risk Related Contingent Features [Abstract]
Collateral required for contracts in net liability positions that have adequate assurance clauses	1,500
Not Designated as Hedging Instrument, Economic Hedge
Unrealized Mark To Market Results [Abstract]
Net unrealized gains/(losses) on open positions related to economic hedges	2,478	2,501	(68)
Commodity contracts
Unrealized Mark To Market Results [Abstract]
Total unrealized gains/(losses)	1,244	2,684	(124)
Commodity contracts \| Operating revenue
Unrealized Mark To Market Results [Abstract]
Total unrealized gains/(losses)	(87)	(196)	90
Commodity contracts \| Cost of operations
Unrealized Mark To Market Results [Abstract]
Total unrealized gains/(losses)	1,315	2,880	(214)
Foreign exchange contract \| Cost of operations
Unrealized Mark To Market Results [Abstract]
Total unrealized gains/(losses)	$ 16	$ 0	$ 0

Nuclear Decommissioning Trust Fund - Summary of Aggregate Fair Values and Realized Gains and Losses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Nuclear decommissioning trust fund disclosure
Fair Value	$ 838	$ 1,008
Unrealized Gains	346	471
Unrealized Losses	36	2
Cash and cash equivalents
Nuclear decommissioning trust fund disclosure
Fair Value	15	33
Unrealized Gains	0	0
Unrealized Losses	0	0
U.S. government and federal agency obligations
Nuclear decommissioning trust fund disclosure
Fair Value	86	112
Unrealized Gains	0	5
Unrealized Losses	$ 5	$ 1
Weighted- average maturities (in years)	11 years	10 years
Federal agency mortgage-backed securities
Nuclear decommissioning trust fund disclosure
Fair Value	$ 101	$ 100
Unrealized Gains	0	2
Unrealized Losses	$ 11	$ 0
Weighted- average maturities (in years)	26 years	25 years
Commercial mortgage-backed securities
Nuclear decommissioning trust fund disclosure
Fair Value	$ 35	$ 44
Unrealized Gains	0	1
Unrealized Losses	$ 4	$ 0
Weighted- average maturities (in years)	30 years	27 years
Corporate debt securities
Nuclear decommissioning trust fund disclosure
Fair Value	$ 114	$ 122
Unrealized Gains	0	7
Unrealized Losses	$ 13	$ 1
Weighted- average maturities (in years)	12 years	14 years
Equity securities
Nuclear decommissioning trust fund disclosure
Fair Value	$ 486	$ 593
Unrealized Gains	346	456
Unrealized Losses	3	0
Foreign government fixed income securities
Nuclear decommissioning trust fund disclosure
Fair Value	1	4
Unrealized Gains	0	0
Unrealized Losses	$ 0	$ 0
Weighted- average maturities (in years)	17 years	13 years
South Texas Project
Nuclear decommissioning trust fund disclosure
Ownership Interest (as a percent)	44.00%

Nuclear Decommissioning Trust Fund - Summary of Proceeds from Sale of Available -for-sale Securities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Regulated Operations [Abstract]
Realized gains	$ 14	$ 47	$ 34
Realized losses	(25)	(9)	(13)
Proceeds from sale of securities	$ 448	$ 710	$ 439

Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Inventory Disclosure [Abstract]
Fuel oil	$ 8	$ 8
Coal	114	83
Natural gas	385	206
Spare parts and finished goods	244	201
Total Inventory	$ 751	$ 498

Property, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Property, Plant and Equipment
Total property, plant, and equipment	$ 3,170	$ 2,996
Accumulated depreciation	(1,478)	(1,308)
Net property, plant, and equipment	1,692	1,688
Depreciation	291	384	$ 295
Facilities and equipment
Property, Plant and Equipment
Total property, plant, and equipment	$ 1,727	1,742
Facilities and equipment \| Minimum
Property, Plant and Equipment
Depreciable lives (in years)	1 year
Facilities and equipment \| Maximum
Property, Plant and Equipment
Depreciable lives (in years)	40 years
Land and improvements
Property, Plant and Equipment
Total property, plant, and equipment	$ 263	271
Nuclear fuel
Property, Plant and Equipment
Total property, plant, and equipment	$ 271	222
Depreciable lives (in years)	5 years
Hardware and office equipment and furnishings
Property, Plant and Equipment
Total property, plant, and equipment	$ 712	637
Hardware and office equipment and furnishings \| Minimum
Property, Plant and Equipment
Depreciable lives (in years)	2 years
Hardware and office equipment and furnishings \| Maximum
Property, Plant and Equipment
Depreciable lives (in years)	10 years
Construction in progress
Property, Plant and Equipment
Total property, plant, and equipment	$ 197	$ 124

Leases - Lease Cost and Other Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Lease, Cost [Abstract]
Finance lease cost	$ 4	$ 4	$ 3
Operating lease cost	85	91	100
Short-term lease cost	7	3	3
Variable lease cost	86	9	6
Sublease income	(2)	(2)	(17)
Total lease cost	180	105	95
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	183	102	101
Financing cash flows from finance leases	5	6	1
Right-of-use assets obtained in exchange for new finance lease liabilities	3	16	5
Right-of-use assets obtained in exchange for new operating lease liabilities	$ 28	$ 47	$ 4
Finance leases:
Weighted average remaining lease term (in years)	2 years 7 months 6 days	3 years 7 months 6 days
Weighted average discount rate	2.82%	2.46%
Operating Leases [Abstract]
Weighted average remaining lease term (in years)	4 years 3 months 18 days	4 years 8 months 12 days
Weighted average discount rate	5.37%	5.44%

Leases - Annual Payments Based on the Maturities of Leases (Details) $ in Millions	Dec. 31, 2022 USD ($)
Leases [Abstract]
2023	$ 97
2024	82
2025	56
2026	14
2027	10
Thereafter	52
Total undiscounted lease payments	311
Less present value adjustment	(48)
Operating lease liability	$ 263

Asset Impairments (Details) - USD ($) $ in Millions	3 Months Ended						12 Months Ended
Asset Impairments (Details) - USD ($) $ in Millions	Sep. 30, 2022	Jun. 30, 2022	Dec. 31, 2021	Jun. 30, 2021	Sep. 30, 2020	Mar. 31, 2020	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Sep. 30, 2019
Asset Impairments
Impairment losses							$ 206	$ 544	$ 75
Goodwill impairment losses		$ 130					130	35
Petra Nova Parish Holdings
Asset Impairments
Impairment losses on equity method investments						$ 18
Letter of credit										$ 12
East
Asset Impairments
Impairment losses	$ 43	$ 20	$ 16				13
Goodwill impairment losses							130	35
East \| Joliet facility
Asset Impairments
Impairment losses			213
East \| PJM Coal Generating Assets
Asset Impairments
Impairment losses				$ 271
Goodwill impairment losses				$ 35
West/Services/Other
Asset Impairments
Impairment losses			$ 9
West/Services/Other \| Held-for-sale \| Home Solar
Asset Impairments
Impairment loss to adjust the carrying amount of assets and liabilities					$ 29
West/Services/Other \| Cottonwood
Asset Impairments
Impairment losses on equity method investments									32
Texas
Asset Impairments
Goodwill impairment losses							$ 0	$ 0
Impairment losses, other assets									$ 14

Goodwill and Other Intangibles - Changes in Goodwill (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2022	Dec. 31, 2021
Goodwill [Roll Forward]
Goodwill, Beginning Balance		$ 1,795	$ 579
Goodwill resulted from the acquisition of Direct Energy			1,250
Impairment losses	$ (130)	(130)	(35)
Asset sales		(6)
Foreign currency translation		(9)	1
Goodwill, Ending Balance		1,650	1,795
Texas
Goodwill [Roll Forward]
Goodwill, Beginning Balance		716	289
Goodwill resulted from the acquisition of Direct Energy			427
Impairment losses		0	0
Asset sales		(6)
Foreign currency translation		0	0
Goodwill, Ending Balance		710	716
East
Goodwill [Roll Forward]
Goodwill, Beginning Balance		853	240
Goodwill resulted from the acquisition of Direct Energy			648
Impairment losses		(130)	(35)
Asset sales		0
Foreign currency translation		0	0
Goodwill, Ending Balance		723	853
West/Services/Other
Goodwill [Roll Forward]
Goodwill, Beginning Balance		226	50
Goodwill resulted from the acquisition of Direct Energy			175
Impairment losses		0	0
Asset sales		0
Foreign currency translation		(9)	1
Goodwill, Ending Balance		$ 217	$ 226

- Definition

Amount after accumulated impairment loss of an asset representing future economic benefits arising from other assets acquired in a business combination that are not individually identified and separately recognized.

+ References + Details

Goodwill and Other Intangibles - Components of Intangible Assets Subject to Amortization (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period	$ 4,147	$ 2,025
Purchases	430	348
Acquisition of businesses	55	2,352
Usage/Sales/Retirements	(374)	(365)
Write-off of fully amortized balances	(14)	(216)
Other	0	3
Balance at end of period	4,244	4,147
Less accumulated amortization	(2,112)	(1,636)
Net carrying amount	2,132	2,511
Renewables Energy Certificates
Finite-lived Intangible Assets [Roll Forward]
Carrying value	186	123
Emission Allowances
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period	634	672
Purchases	26	10
Acquisition of businesses	0	0
Usage/Sales/Retirements	(33)	(1)
Write-off of fully amortized balances	(14)	(51)
Other	11	4
Balance at end of period	624	634
Less accumulated amortization	(528)	(536)
Net carrying amount	96	98
Customer and Supply Contracts
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period	638	28
Purchases	0	0
Acquisition of businesses	0	610
Usage/Sales/Retirements	0	0
Write-off of fully amortized balances	0	0
Other	(3)	0
Balance at end of period	635	638
Less accumulated amortization	(235)	(94)
Net carrying amount	400	544
Customer Relationships
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period	1,679	527
Purchases	0	0
Acquisition of businesses	55	1,308
Usage/Sales/Retirements	0	0
Write-off of fully amortized balances	0	(158)
Other	(4)	2
Balance at end of period	1,730	1,679
Less accumulated amortization	(787)	(518)
Net carrying amount	$ 943	$ 1,161
Weighted average useful life, years	6 years	12 years
Marketing Partnerships
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period	$ 284	$ 285
Purchases	0	0
Acquisition of businesses	0	0
Usage/Sales/Retirements	0	0
Write-off of fully amortized balances	0	0
Other	0	(1)
Balance at end of period	284	284
Less accumulated amortization	(146)	(123)
Net carrying amount	138	161
Trade Names
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period	683	373
Purchases	0	0
Acquisition of businesses	0	310
Usage/Sales/Retirements	0	0
Write-off of fully amortized balances	0	0
Other	(4)	0
Balance at end of period	679	683
Less accumulated amortization	(341)	(294)
Net carrying amount	338	389
Other
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period	229	140
Purchases	404	338
Acquisition of businesses	0	124
Usage/Sales/Retirements	(341)	(364)
Write-off of fully amortized balances	0	(7)
Other	0	(2)
Balance at end of period	292	229
Less accumulated amortization	(75)	(71)
Net carrying amount	$ 217	$ 158

Goodwill and Other Intangibles - Schedule of Amortization and Retirement of Intangible Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Finite-Lived Intangible Assets [Line Items]
Total amortization	$ 490	$ 495	$ 168
Depreciation and amortization	634	785	435
Emission Allowances
Finite-Lived Intangible Assets [Line Items]
Total amortization	6	24	28
Customer and Supply Contracts
Finite-Lived Intangible Assets [Line Items]
Total amortization	141	66	12
Customer Relationships
Finite-Lived Intangible Assets [Line Items]
Total amortization	269	327	74
Marketing Partnerships
Finite-Lived Intangible Assets [Line Items]
Total amortization	23	24	24
Trade Names
Finite-Lived Intangible Assets [Line Items]
Total amortization	47	47	27
Other
Finite-Lived Intangible Assets [Line Items]
Total amortization	4	7	3
Depreciation and amortization	$ 4	$ 3	$ 3

Goodwill and Other Intangibles - Schedule of Estimated Amortization of Intangible Asset for the Next Five Years (Details) $ in Millions	Dec. 31, 2022 USD ($)
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2023	$ 436
2024	315
2025	243
2026	213
2027	162
Emission Allowances
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2023	18
2024	19
2025	18
2026	10
2027	10
Customer and Supply Contracts
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2023	119
2024	73
2025	50
2026	52
2027	30
Customer Relationships
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2023	226
2024	159
2025	118
2026	103
2027	74
Marketing Partnerships
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2023	23
2024	23
2025	22
2026	22
2027	22
Trade Names
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2023	46
2024	38
2025	31
2026	23
2027	23
Other
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2023	4
2024	3
2025	4
2026	3
2027	$ 3

Goodwill and Other Intangibles - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Held-for-sale
Goodwill and Other Intangibles
Emission allowances held-for-sale	$ 8	$ 15

Asset Retirement Obligations (Details) $ in Millions	12 Months Ended
Asset Retirement Obligations (Details) $ in Millions	Dec. 31, 2022 USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance as of December 31, 2021	$ 720
Revisions in estimates for current obligations	38
Additions	1
Spending for current obligations	(33)
Accretion	38
Other	(6)
Balance as of December 31, 2022	758
Nuclear Decommission
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance as of December 31, 2021	321
Revisions in estimates for current obligations	0
Additions	0
Spending for current obligations	0
Accretion	19
Other	0
Balance as of December 31, 2022	340
Other
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance as of December 31, 2021	399
Revisions in estimates for current obligations	38
Additions	1
Spending for current obligations	(33)
Accretion	19
Other	(6)
Balance as of December 31, 2022	$ 418

Long-term Debt and Finance Leases - Schedule of Long-term Debt and Finance Leases (Details) $ / shares in Units, $ in Millions		12 Months Ended
	Jan. 31, 2023 $ / shares	Dec. 31, 2022 USD ($) $ / shares	Dec. 31, 2021 USD ($) $ / shares	Aug. 23, 2021	Dec. 02, 2020	May 24, 2019	Dec. 07, 2017	Aug. 02, 2016
Debt Instrument [Line Items]
Long-term debt		$ 8,100	$ 8,100
Finance leases		$ 11	$ 13
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]		Total long-term debt and finance leases	Total long-term debt and finance leases
Total long-term debt and finance lease obligations		$ 8,111	$ 8,113
Less current maturities		(63)	(4)
Less debt issuance costs		(70)	(83)
Discounts		(2)	(60)
Total long-term debt and finance leases		7,976	7,966
Debt Instrument, Unamortized Discount [Abstract]
Total discounts		$ (2)	(60)
Senior Notes, due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage		6.625%		6.625%
Senior Notes, due 2032
Debt Instrument [Line Items]
Interest rate, stated percentage				3.875%
Tax-exempt bonds
Debt Instrument [Line Items]
Long-term debt		$ 466	466
Recourse Debt \| Senior Notes, due 2027
Debt Instrument [Line Items]
Long-term debt		$ 375	375
Interest rate, stated percentage		6.625%						6.625%
Recourse Debt \| Senior Notes, due 2028
Debt Instrument [Line Items]
Long-term debt		$ 821	821
Interest rate, stated percentage		5.75%					5.75%
Recourse Debt \| Senior Notes, due 2029
Debt Instrument [Line Items]
Long-term debt		$ 733	733
Interest rate, stated percentage		5.25%				5.25%
Recourse Debt \| Senior Notes, due 2029
Debt Instrument [Line Items]
Long-term debt		$ 500	500
Interest rate, stated percentage		3.375%			3.375%
Recourse Debt \| Senior Notes, due 2031
Debt Instrument [Line Items]
Long-term debt		$ 1,030	1,030
Interest rate, stated percentage		3.625%
Recourse Debt \| Senior Notes, due 2032
Debt Instrument [Line Items]
Long-term debt		$ 1,100	1,100
Interest rate, stated percentage		3.875%
Recourse Debt \| Convertible Senior Notes Due 2048
Debt Instrument [Line Items]
Long-term debt		$ 575	575
Discounts		$ 0	$ (58)
Interest rate, stated percentage		2.75%
Conversion price per common share (in usd per share) \| $ / shares		$ 43.46	$ 44.89
Conversion ratio		0.0230116	0.0222761
Debt Instrument, Unamortized Discount [Abstract]
Total discounts		$ 0	$ (58)
Recourse Debt \| Convertible Senior Notes Due 2048 \| Subsequent Event
Debt Instrument [Line Items]
Conversion price per common share (in usd per share) \| $ / shares	$ 43.01
Conversion ratio	0.0232527
Recourse Debt \| Senior Secured First Lien Notes, due 2024
Debt Instrument [Line Items]
Long-term debt		$ 600	600
Interest rate, stated percentage		3.75%
Recourse Debt \| Senior Secured First Lien Notes, due 2025
Debt Instrument [Line Items]
Long-term debt		$ 500	500
Interest rate, stated percentage		2.00%
Recourse Debt \| Senior Secured First Lien Notes, due 2027
Debt Instrument [Line Items]
Long-term debt		$ 900	900
Interest rate, stated percentage		2.45%
Recourse Debt \| Senior Secured First Lien Notes, due 2029
Debt Instrument [Line Items]
Long-term debt		$ 500	500
Interest rate, stated percentage		4.45%
Recourse Debt \| Tax-exempt bonds
Debt Instrument [Line Items]
Long-term debt		$ 466	466
Recourse Debt \| Tax-exempt bonds \| Minimum
Debt Instrument [Line Items]
Interest rate, stated percentage		1.25%
Recourse Debt \| Tax-exempt bonds \| Maximum
Debt Instrument [Line Items]
Interest rate, stated percentage		4.75%
Recourse Debt \| Senior Secured First Lien Notes, due 2024, 2025, 2027 and 2029
Debt Instrument [Line Items]
Discounts		$ (2)	(2)
Debt Instrument, Unamortized Discount [Abstract]
Total discounts		$ (2)	$ (2)

Long-term Debt and Finance Leases - Annual Payments Based on the Maturities of Debt and Capital Leases (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Debt Disclosure [Abstract]
2023	$ 63
2024	604
2025	749
2026	1
2027	1,275
Thereafter	5,419
Total long-term debt and finance lease obligations	$ 8,111	$ 8,113

Long-term Debt and Finance Leases - Revolving Credit Facility (Details) - Revolving Credit Facility Agreement - USD ($) $ in Millions	Feb. 14, 2023	Dec. 31, 2022
Revolving Credit Facility
Line of Credit Facility [Line Items]
Borrowings outstanding		$ 0
Revolving Credit Facility \| Subsequent Event
Line of Credit Facility [Line Items]
Increase in existing borrowing commitments	$ 600
Revolving credit facility	4,275
Credit facility, decrease if acquisition is not consummated	$ 500
Collateral exclusion for percentage of equity interests that exceeds total outstanding voting equity interests of certain foreign subsidiaries	66.00%
Collateral excluded, subsidiaries and other assets aggregate fair value, maximum	$ 750
Letter of Credit
Line of Credit Facility [Line Items]
Letter of credit		$ 1,600

Long-term Debt and Finance Leases - Senior Notes Issuance and Redemptions (Details) - USD ($)		12 Months Ended
	Aug. 23, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Principal repurchased		$ 1,855,000,000
Repayment of senior notes		1,949,000,000
Loss on debt extinguishment		$ 0	$ (77,000,000)	$ (9,000,000)
Write off of deferred debt issuance cost			12,000,000
Senior Notes, due 2032
Debt Instrument [Line Items]
Aggregate principal amount	$ 1,100,000,000
Interest rate, stated percentage	3.875%
Increase in basis points if sustainability targets are not achieved	0.25%
Senior Notes due 2026
Debt Instrument [Line Items]
Interest rate, stated percentage	7.25%	7.25%
Principal repurchased	$ 1,000,000,000	$ 1,000,000,000
Repayment of senior notes		$ 1,056,000,000
Senior Notes, due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage	6.625%	6.625%
Principal repurchased	$ 355,000,000	$ 855,000,000
Repayment of senior notes		$ 893,000,000
Senior Notes
Debt Instrument [Line Items]
Principal repurchased			1,900,000,000
Repayment of senior notes			1,900,000,000
Loss on debt extinguishment			$ 77,000,000

Long-term Debt and Finance Leases - Senior Notes Redemptions (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Aug. 23, 2021
Debt Instrument [Line Items]
Principal Repurchased	$ 1,855,000,000
Cash Paid	$ 1,949,000,000
Accrued interest		$ 29,000,000
Senior Notes due 2026
Debt Instrument [Line Items]
Interest rate, stated percentage	7.25%		7.25%
Principal Repurchased	$ 1,000,000,000		$ 1,000,000,000
Cash Paid	$ 1,056,000,000
Average Early Redemption Percentage	103.625%
Senior Notes, due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage	6.625%		6.625%
Principal Repurchased	$ 855,000,000		$ 355,000,000
Cash Paid	$ 893,000,000
Average Early Redemption Percentage	103.313%

Long-term Debt and Finance Leases - Issuance of Convertible Senior Notes (Details) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) $ / shares	Dec. 31, 2021 USD ($) $ / shares	Dec. 31, 2018	Jan. 01, 2022 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance	$ 3,828	$ 3,600			$ 1,680	$ 1,658
Deferred tax liabilities	(1,270)	(1,090)
Additional Paid-In Capital
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance	8,457	8,531			8,517	8,501
Retained Earnings
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance	$ 1,408	464			$ (1,403)	$ (1,616)
Cumulative Effect, Period of Adoption, Adjustment
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance		(43)
Debt discount				$ 57
Deferred tax liabilities				14
Cumulative Effect, Period of Adoption, Adjustment \| Additional Paid-In Capital
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance		(100)		(100)
Cumulative Effect, Period of Adoption, Adjustment \| Retained Earnings
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance		$ 57		$ 57
Convertible Senior Notes Due 2048
Debt Instrument [Line Items]
Debt discount amortization period			7 years
Convertible Senior Notes Due 2048 \| Recourse Debt
Debt Instrument [Line Items]
Conversion price per common share (in usd per share) \| $ / shares	$ 43.46	$ 44.89
Conversion ratio	0.0230116	0.0222761
Carrying amount of equity component	$ 570	$ 512

Long-term Debt and Finance Leases - Interest Expense in Connection with Convertible Senior Notes, due 2048 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Amortization of discount and deferred finance costs	$ 23	$ 39	$ 48
Convertible Senior Notes Due 2048 \| Recourse Debt
Debt Instrument [Line Items]
Contractual interest expense	16	16	16
Amortization of discount and deferred finance costs	1	15	14
Total	$ 17	$ 31	$ 30
Effective Interest Rate	3.01%	5.34%	5.19%

Long-term Debt and Finance Leases - Senior Notes Outstanding with Early Redemption Features (Details)	12 Months Ended
	Dec. 31, 2022	Aug. 23, 2021	Dec. 02, 2020	May 24, 2019	Dec. 07, 2017	Aug. 02, 2016
6.625% Senior Notes due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage	6.625%	6.625%
Senior Notes, due 2032
Debt Instrument [Line Items]
Interest rate, stated percentage		3.875%
Recourse Debt \| 6.625% Senior Notes due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage	6.625%					6.625%
Recourse Debt \| 5.750% Senior Notes due 2028
Debt Instrument [Line Items]
Interest rate, stated percentage	5.75%				5.75%
Recourse Debt \| 5.250% Senior Notes due 2029
Debt Instrument [Line Items]
Interest rate, stated percentage	5.25%			5.25%
Recourse Debt \| 3.375% Senior Notes due 2029
Debt Instrument [Line Items]
Interest rate, stated percentage	3.375%		3.375%
Recourse Debt \| Senior Notes due 2031
Debt Instrument [Line Items]
Interest rate, stated percentage			3.625%
Recourse Debt \| Senior Notes, due 2032
Debt Instrument [Line Items]
Interest rate, stated percentage	3.875%
Recourse Debt \| Senior Notes \| Low
Debt Instrument [Line Items]
Redemption percentage of principal	25.00%
Recourse Debt \| Senior Notes \| Maximum
Debt Instrument [Line Items]
Redemption percentage of principal	30.00%

Long-term Debt and Finance Leases - Senior Notes Redemption Period (Details)	12 Months Ended
	Dec. 31, 2022	Aug. 23, 2021	Dec. 02, 2020	May 24, 2019	Dec. 07, 2017	Aug. 02, 2016
6.625% Senior Notes due 2027
Debt Instrument [Line Items]
Redemption Percentage	103.313%
Interest rate, stated percentage	6.625%	6.625%
Senior Notes, due 2032
Debt Instrument [Line Items]
Redemption Percentage	40.00%
Interest rate, stated percentage		3.875%
Senior Notes, due 2032 \| Redemption Period Prior to August 15 2024
Debt Instrument [Line Items]
Redemption Percentage	103.875%
Outstanding principal after redemption, percentage (at least)	50.00%
Senior Notes, due 2032 \| Redemption Period Prior to February 15 2027
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Premium percentage of principal amount of note discount factor (as percent)	1.00%
Senior Notes, due 2032 \| 2027
Debt Instrument [Line Items]
Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)	101.938%
Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)	102.188%
Senior Notes, due 2032 \| 2028
Debt Instrument [Line Items]
Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)	101.292%
Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)	101.458%
Senior Notes, due 2032 \| 2029
Debt Instrument [Line Items]
Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)	100.646%
Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)	100.729%
Senior Notes, due 2032 \| 2030 and thereafter
Debt Instrument [Line Items]
Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)	100.00%
Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)	100.00%
Recourse Debt \| 6.625% Senior Notes due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage	6.625%					6.625%
Recourse Debt \| 6.625% Senior Notes due 2027 \| July 15, 2022 to July 14, 2023
Debt Instrument [Line Items]
Redemption Percentage	102.208%
Recourse Debt \| 6.625% Senior Notes due 2027 \| July 15, 2023 to July 14, 2024
Debt Instrument [Line Items]
Redemption Percentage	101.104%
Recourse Debt \| 6.625% Senior Notes due 2027 \| July 15, 2024 and thereafter
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Recourse Debt \| 5.750% Senior Notes due 2028
Debt Instrument [Line Items]
Interest rate, stated percentage	5.75%				5.75%
Recourse Debt \| 5.750% Senior Notes due 2028 \| January 15, 2023 to January 14, 2024
Debt Instrument [Line Items]
Redemption Percentage	102.875%
Recourse Debt \| 5.750% Senior Notes due 2028 \| January 15, 2024 to January 14, 2025
Debt Instrument [Line Items]
Redemption Percentage	101.917%
Recourse Debt \| 5.750% Senior Notes due 2028 \| January 15, 2025 to January 14, 2026
Debt Instrument [Line Items]
Redemption Percentage	100.958%
Recourse Debt \| 5.750% Senior Notes due 2028 \| January 15, 2026 and thereafter
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Recourse Debt \| 5.250% Senior Notes due 2029
Debt Instrument [Line Items]
Interest rate, stated percentage	5.25%			5.25%
Recourse Debt \| 5.250% Senior Notes due 2029 \| Treasury Rate
Debt Instrument [Line Items]
Treasury rate redemption (as percentage)	0.50%
Recourse Debt \| 5.250% Senior Notes due 2029 \| Redemption Period Prior to June 15, 2024
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Premium percentage of principal amount of note discount factor (as percent)	1.00%
Present value of note (as percentage)	1.02625
Recourse Debt \| 5.250% Senior Notes due 2029 \| June 15, 2024 to June 14, 2025
Debt Instrument [Line Items]
Redemption Percentage	102.625%
Recourse Debt \| 5.250% Senior Notes due 2029 \| June 15, 2025 to June 14, 2026
Debt Instrument [Line Items]
Redemption Percentage	101.75%
Recourse Debt \| 5.250% Senior Notes due 2029 \| June 15, 2026 to June 14, 2027
Debt Instrument [Line Items]
Redemption Percentage	100.875%
Recourse Debt \| 5.250% Senior Notes due 2029 \| June 15, 2027 and thereafter
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Recourse Debt \| 3.375% Senior Notes Due 2029
Debt Instrument [Line Items]
Redemption Percentage	40.00%
Interest rate, stated percentage	3.375%		3.375%
Recourse Debt \| 3.375% Senior Notes Due 2029 \| Treasury Rate
Debt Instrument [Line Items]
Treasury rate redemption (as percentage)	0.50%
Recourse Debt \| 3.375% Senior Notes Due 2029 \| Redemption Period Prior to February 15, 2024
Debt Instrument [Line Items]
Redemption Percentage	103.375%
Premium percentage of principal amount of note discount factor (as percent)	1.00%
Present value of note (as percentage)	1.01688
Outstanding principal after redemption, percentage (at least)	50.00%
Recourse Debt \| 3.375% Senior Notes Due 2029 \| February 15, 2024 to February 14, 2025
Debt Instrument [Line Items]
Redemption Percentage	101.688%
Recourse Debt \| 3.375% Senior Notes Due 2029 \| February 15, 2025 to February 14, 2026
Debt Instrument [Line Items]
Redemption Percentage	100.844%
Recourse Debt \| 3.375% Senior Notes Due 2029 \| February 15, 2026 and thereafter
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Recourse Debt \| Senior Notes due 2031
Debt Instrument [Line Items]
Redemption Percentage	40.00%
Interest rate, stated percentage			3.625%
Recourse Debt \| Senior Notes due 2031 \| Treasury Rate
Debt Instrument [Line Items]
Treasury rate redemption (as percentage)	0.50%
Recourse Debt \| Senior Notes due 2031 \| Redemption Period Prior to February 15, 2026
Debt Instrument [Line Items]
Redemption Percentage	103.625%
Premium percentage of principal amount of note discount factor (as percent)	1.00%
Outstanding principal after redemption, percentage (at least)	50.00%
Recourse Debt \| Senior Notes due 2031 \| February 15, 2026 to February 14, 2027
Debt Instrument [Line Items]
Redemption Percentage	101.813%
Present value of note (as percentage)	1.01813
Recourse Debt \| Senior Notes due 2031 \| February 15, 2027 to February 14, 2028
Debt Instrument [Line Items]
Redemption Percentage	101.208%
Recourse Debt \| Senior Notes due 2031 \| February 15, 2028 to February 14, 2029
Debt Instrument [Line Items]
Redemption Percentage	100.604%
Recourse Debt \| Senior Notes due 2031 \| February 15, 2029 and thereafter
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Recourse Debt \| Senior Notes, due 2032
Debt Instrument [Line Items]
Interest rate, stated percentage	3.875%
Recourse Debt \| Senior Notes, due 2032 \| Treasury Rate
Debt Instrument [Line Items]
Treasury rate redemption (as percentage)	0.50%

Long-term Debt and Finance Leases - Receivables Securitizations and Repurchase Facility (Details) - Secured Debt - USD ($)	Jul. 26, 2022	Sep. 22, 2020	Dec. 31, 2022	Jun. 30, 2022	Feb. 09, 2022	Dec. 31, 2021	Dec. 31, 2020
Receivables Facility
Debt Instrument [Line Items]
Credit facility							$ 750,000,000
Receivables Facility \| Revolving Credit Facility
Debt Instrument [Line Items]
Credit facility	$ 1,000,000,000			$ 800,000,000
Receivable facility, extension period	1 year
Weighted average interest rate			0.844%
Borrowings outstanding			$ 0
Receivables Facility \| Letter of Credit
Debt Instrument [Line Items]
Letter of credit			721,000,000
Repurchase Facility
Debt Instrument [Line Items]
Credit facility					$ 150,000,000	$ 75,000,000	$ 75,000,000
Borrowings outstanding			$ 0
Commitment fee		$ 0
Repurchase Facility \| SOFR
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)		1.30%

Long-term Debt and Finance Leases - Bilateral letter of Credit Facilities (Details) - Bilateral Letter of Credit Facilities - Letter of Credit - USD ($)	Oct. 13, 2022	May 27, 2022	Apr. 29, 2022	Dec. 31, 2022
Debt Instrument [Line Items]
Increase in revolving commitments and letters of credit	$ 50,000,000	$ 50,000,000	$ 100,000,000
Letter of credit				$ 668,000,000
Revolving credit facility				$ 675,000,000

Long-term Debt and Finance Leases - Tax Exempt Bonds (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Long-term debt	$ 8,100	$ 8,100
NRG Indian River Power 2020, tax exempt bonds, due 2040
Debt Instrument [Line Items]
Long-term debt	$ 57	57
Interest rate, stated percentage	1.25%
NRG Indian River Power 2020, tax exempt bonds, due 2045
Debt Instrument [Line Items]
Long-term debt	$ 190	190
Interest rate, stated percentage	1.25%
NRG Dunkirk 2020, tax exempt bonds, due 2042
Debt Instrument [Line Items]
Long-term debt	$ 59	59
Interest rate, stated percentage	1.30%
City of Texas City, tax exempt bonds, due 2045
Debt Instrument [Line Items]
Long-term debt	$ 33	33
Interest rate, stated percentage	4.125%
Fort Bend County, tax exempt bonds, due 2038
Debt Instrument [Line Items]
Long-term debt	$ 54	54
Interest rate, stated percentage	4.75%
Fort Bend County, tax exempt bonds, due 2042
Debt Instrument [Line Items]
Long-term debt	$ 73	73
Interest rate, stated percentage	4.75%
Tax-exempt bonds
Debt Instrument [Line Items]
Long-term debt	$ 466	$ 466

Benefit Plans and Other Postretirement Benefits - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) benefitPlan	Dec. 31, 2021 USD ($)
Benefit Plans and Other Postretirement Benefits
Number of qualified pension plans \| benefitPlan	3
Pension Benefits
Benefit Plans and Other Postretirement Benefits
Expects to contribute to the pension plans	$ 83
Actuarial gain	289	$ 55
Pension Benefits \| GenOn
Benefit Plans and Other Postretirement Benefits
Expects to contribute to the pension plans	$ 45

Benefit Plans and Other Postretirement Benefits - Net Benefit Costs and Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Pension Benefits
Annual periodic pension cost
Service cost benefits earned	$ 7	$ 9	$ 10
Interest cost on benefit obligation	41	27	38
Expected return on plan assets	(47)	(66)	(61)
Amortization of unrecognized net loss	3	1	5
Curtailment loss	14	2	0
Net periodic benefit cost/(credit)	18	(27)	(8)
Pension and other post retirement benefit obligations
Benefit obligation at January 1	1,452	1,489
Acquired benefit obligation from Direct Energy	0	74
Service cost	7	9	10
Interest cost	41	27	38
Actuarial gain	(289)	(55)
Employee and retiree contributions	0	0
Curtailment loss	0	0
Benefit payments	(171)	(93)
Foreign exchange translation	(4)	1
Benefit obligation at December 31	1,036	1,452	1,489
Fair value of plan assets for pension and other post retirement benefit
Fair value of plan assets at January 1	1,336	1,272
Acquired fair value of plan assets from Direct Energy	0	64
Actual return on plan assets	(317)	85
Employee and retiree contributions	0	0
Employer contributions	0	7
Benefit payments	(171)	(93)
Foreign exchange translation	(4)	1
Fair value of plan assets at December 31	844	1,336	1,272
Funded status at December 31 — excess of obligation over assets	(192)	(116)
Other Postretirement Benefits Plan
Annual periodic pension cost
Service cost benefits earned	0	0
Interest cost on benefit obligation	2	2	3
Amortization of unrecognized prior service cost	(8)	(10)	(14)
Amortization of unrecognized net loss	2	1	1
Curtailment loss	0	1	0
Net periodic benefit cost/(credit)	(4)	(6)	(10)
Pension and other post retirement benefit obligations
Benefit obligation at January 1	105	90
Acquired benefit obligation from Direct Energy	0	19
Service cost	0	0
Interest cost	2	2	3
Actuarial gain	(11)	0
Employee and retiree contributions	3	3
Curtailment loss	0	1
Benefit payments	(15)	(10)
Foreign exchange translation	0	0
Benefit obligation at December 31	84	105	90
Fair value of plan assets for pension and other post retirement benefit
Fair value of plan assets at January 1	0	0
Acquired fair value of plan assets from Direct Energy	0	0
Actual return on plan assets	0	0
Employee and retiree contributions	3	3
Employer contributions	12	7
Benefit payments	(15)	(10)
Foreign exchange translation	0	0
Fair value of plan assets at December 31	0	0	$ 0
Funded status at December 31 — excess of obligation over assets	$ (84)	$ (105)

Benefit Plans and Other Postretirement Benefits - Amounts Recognized in the Balance Sheets and OCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Pension Benefits
Amounts recognized in balance sheet
Other current liabilities	$ 0	$ 0
Other non-current liabilities	192	116
Amounts recognized in accumulated OCI
Net loss/(gain)	110	52
Prior service cost/(credit)	1	2
Total/Net accumulated OCI	111	54
Other changes in plan assets and benefit obligations recognized in other comprehensive income
Net actuarial loss/(gain)	74	(72)
Amortization of net actuarial loss	(3)	(1)
Amortization of prior service cost	0	0
Effect of settlement/curtailment	(14)	(2)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	57	(75)
Net periodic benefit cost/(credit)	18	(27)	$ (8)
Net recognized in net periodic pension cost/(credit) and OCI	75	(102)
Significant components of NRG's domestic pension plan
Projected benefit obligation	1,036	1,452	1,489
Accumulated benefit obligation	1,022	1,423
Fair value of plan assets	844	1,336	1,272
Other Postretirement Benefits Plan
Amounts recognized in balance sheet
Other current liabilities	7	7
Other non-current liabilities	77	98
Amounts recognized in accumulated OCI
Net loss/(gain)	(7)	5
Prior service cost/(credit)	(12)	(19)
Total/Net accumulated OCI	(19)	(14)
Other changes in plan assets and benefit obligations recognized in other comprehensive income
Net actuarial loss/(gain)	(11)	0
Amortization of net actuarial loss	(2)	(1)
Amortization of prior service cost	8	10
Effect of settlement/curtailment	0	0
Other changes in plan assets and benefit obligations recognized in other comprehensive income	(5)	9
Net periodic benefit cost/(credit)	(4)	(6)	(10)
Net recognized in net periodic pension cost/(credit) and OCI	(9)	3
Significant components of NRG's domestic pension plan
Projected benefit obligation	84	105	90
Fair value of plan assets	$ 0	$ 0	$ 0

Benefit Plans and Other Postretirement Benefits - Fair Values of Pension Assets By Asset Category and Level Within the Fair Value Hierarchy (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Minimum
Significant assumptions used to calculate NRG's benefit expense
Aon Hewitt above median yield curve discount rate (in years)	6 months
Maximum
Significant assumptions used to calculate NRG's benefit expense
Aon Hewitt above median yield curve discount rate (in years)	99 years
Pension Benefits
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	$ 844	$ 1,336	$ 1,272
Weighted-Average Assumptions
Discount rate	5.18%	2.89%
Interest crediting rate	5.21%	3.07%
Rate of compensation increase	3.06%	3.06%
Significant assumptions used to calculate NRG's benefit expense
Discount rate		2.55%	3.26%
Interest crediting rate	3.07%	3.13%	3.66%
Expected return on plan assets	4.99%	5.62%	5.93%
Rate of compensation increase	3.06%	3.06%	3.00%
Pension Benefits \| Minimum
Significant assumptions used to calculate NRG's benefit expense
Discount rate	2.89%
Pension Benefits \| Weighted Average
Significant assumptions used to calculate NRG's benefit expense
Discount rate	4.71%
Pension Benefits \| Maximum
Significant assumptions used to calculate NRG's benefit expense
Discount rate	5.41%
Pension Benefits \| Common/collective trust investment — U.S. equity
Target allocations
Target allocation of pension plan assets (as percent)	21.00%
Pension Benefits \| Common/collective trust investment — non-U.S. equity
Target allocations
Target allocation of pension plan assets (as percent)	14.00%
Pension Benefits \| Common/collective trust investment — non-core assets
Target allocations
Target allocation of pension plan assets (as percent)	18.00%
Pension Benefits \| Common/collective trust investment — fixed income
Target allocations
Target allocation of pension plan assets (as percent)	47.00%
Pension Benefits \| Quoted Prices in Active Markets for Identical Assets (Level 1)
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	$ 22	$ 13
Pension Benefits \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Common/collective trust investment — U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	0	0
Pension Benefits \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Common/collective trust investment — non-U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	0	0
Pension Benefits \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Common/collective trust investment — non-core assets
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	0	0
Pension Benefits \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Common/collective trust investment — fixed income
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	0	0
Pension Benefits \| Quoted Prices in Active Markets for Identical Assets (Level 1) \| Short-term investment fund
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	22	13
Pension Benefits \| Significant Observable Inputs (Level 2)
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	491	740
Pension Benefits \| Significant Observable Inputs (Level 2) \| Common/collective trust investment — U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	155	221
Pension Benefits \| Significant Observable Inputs (Level 2) \| Common/collective trust investment — non-U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	65	69
Pension Benefits \| Significant Observable Inputs (Level 2) \| Common/collective trust investment — non-core assets
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	90	110
Pension Benefits \| Significant Observable Inputs (Level 2) \| Common/collective trust investment — fixed income
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	181	340
Pension Benefits \| Significant Observable Inputs (Level 2) \| Short-term investment fund
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	0	0
Pension Benefits \| Total
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	513	753
Pension Benefits \| Total \| Common/collective trust investment — U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	155	221
Pension Benefits \| Total \| Common/collective trust investment — non-U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	65	69
Pension Benefits \| Total \| Common/collective trust investment — non-core assets
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	90	110
Pension Benefits \| Total \| Common/collective trust investment — fixed income
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	181	340
Pension Benefits \| Total \| Short-term investment fund
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	22	13
Pension Benefits \| Net Asset Value
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	844	1,336
Pension Benefits \| Net Asset Value \| Common/collective trust investment — non-U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	33	78
Pension Benefits \| Net Asset Value \| Common/collective trust investment — non-core assets
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	55	65
Pension Benefits \| Net Asset Value \| Common/collective trust investment — fixed income
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	220	405
Pension Benefits \| Net Asset Value \| Partnerships/joint ventures
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	23	35
Other Postretirement Benefits Plan
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	$ 0	$ 0	$ 0
Weighted-Average Assumptions
Discount rate	5.19%	2.89%
Interest crediting rate	4.00%	1.94%
Rate of compensation increase	0.00%	0.00%
Health care trend rate	7.00%	6.80%
Health care trend rate	4.40%	4.40%
Year Health care cost trend rate reaches ultimate trend rate	2031	2028
Significant assumptions used to calculate NRG's benefit expense
Discount rate	2.82%	2.81%	3.26%
Interest crediting rate	1.94%	1.62%	2.28%
Expected return on plan assets	0.00%	0.00%	0.00%
Rate of compensation increase	0.00%	0.00%	0.00%
Health care trend rate	7.00%	6.80%
Year Health care cost trend rate reaches ultimate trend rate	2031	2028
Other Postretirement Benefits Plan \| Net Period Benefit Cost/Credit
Weighted-Average Assumptions
Health care trend rate	6.90%	7.00%	7.50%
Health care trend rate	4.40%	4.40%	4.50%
Year Health care cost trend rate reaches ultimate trend rate	2028	2028	2028
Significant assumptions used to calculate NRG's benefit expense
Health care trend rate	6.90%	7.00%	7.50%
Year Health care cost trend rate reaches ultimate trend rate	2028	2028	2028

Benefit Plans and Other Postretirement Benefits - Expected Future Benefit Payments For the Next Five Years and Other (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Company's contributions to 401(k) plans
Company contributions to defined contribution plans	$ 26	$ 25	$ 22
South Texas Project
STP Defined Benefit Plans
Amount reimbursed to STPNOC towards defined benefit plans	18	17
Expected reimbursement of contribution to retirement plan obligations to STPNOC in 2023	10
Benefit Payments
NRG's expected future benefit payments
2023	83
2024	81
2025	79
2026	77
2027	76
2028-2032	361
STP Defined Benefit Plans
Curtailment gain	(14)	(2)	0
Increase to pension liability	0	0
Recognized amount in statement of financial position, statement of operations and accumulated OCI related to STP
Funded status — STPNOC benefit plans	(192)	(116)
Net periodic benefit cost/(credit)	18	(27)	(8)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	57	(75)
Benefit Payments \| South Texas Project
Recognized amount in statement of financial position, statement of operations and accumulated OCI related to STP
Funded status — STPNOC benefit plans	(7)	(50)
Net periodic benefit cost/(credit)	2	17
Other changes in plan assets and benefit obligations recognized in other comprehensive income	(27)	(51)
Other Postretirement Benefits Plan
NRG's expected future benefit payments
2023	7
2024	7
2025	6
2026	6
2027	6
2028-2032	27
Medicare prescription drug reimbursements
2023	0
2024	0
2025	0
2026	0
2027	0
2028-2032	2
STP Defined Benefit Plans
Curtailment gain	0	(1)	0
Increase to pension liability	0	(1)
Recognized amount in statement of financial position, statement of operations and accumulated OCI related to STP
Funded status — STPNOC benefit plans	(84)	(105)
Net periodic benefit cost/(credit)	(4)	(6)	$ (10)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	(5)	9
Other Postretirement Benefits Plan \| South Texas Project
Recognized amount in statement of financial position, statement of operations and accumulated OCI related to STP
Funded status — STPNOC benefit plans	(13)	(18)
Net periodic benefit cost/(credit)	(4)	(4)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	$ 1	$ 4
South Texas Project
STP Defined Benefit Plans
Ownership interest in STP (as a percent)	44.00%
Percentage of contribution to the retirement plan obligation reimbursed	44.00%

Capital Structure - Changes in Common Shares issued and Outstanding (Details) - shares	2 Months Ended	12 Months Ended
	Feb. 15, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Capital Structure
Preferred stock, shares authorized (in shares)		10,000,000	10,000,000	10,000,000	10,000,000
Common stock, shares authorized (in shares)		500,000,000	500,000,000	500,000,000	500,000,000
Increase (Decrease) in Stockholders' Equity (in shares)
Beginning balance, common shares issued (in shares)	423,897,001	423,547,174
Beginning balance, treasury shares (in shares)	(194,335,971)	(179,793,275)
Beginning balance, common shares outstanding (in shares)	229,561,030	243,753,899
Share repurchases (in shares)		(14,685,521)	(1,084,752)	(6,062,783)
Ending balance, common shares issued (in shares)		423,897,001	423,547,174
Ending balance, treasury shares (in shares)		(194,335,971)	(179,793,275)
Ending balance, common shares outstanding (in shares)		229,561,030	243,753,899
Common Stock
Increase (Decrease) in Stockholders' Equity (in shares)
Beginning balance, common shares issued (in shares)	423,897,001	423,547,174	423,057,848	421,890,790
Beginning balance, common shares outstanding (in shares)	229,561,030	243,753,899	244,231,933	248,996,189
Shares issued under ESPP (in shares)		142,825	117,392	131,469
Shares issued from LTIP (in shares)		349,827	489,326	1,167,058
Ending balance, common shares issued (in shares)		423,897,001	423,547,174	423,057,848
Ending balance, common shares outstanding (in shares)		229,561,030	243,753,899	244,231,933
Common Stock \| Subsequent Event
Increase (Decrease) in Stockholders' Equity (in shares)
Shares issued from LTIP (in shares)	213,208
Ending balance, common shares issued (in shares)	424,110,209
Ending balance, common shares outstanding (in shares)	229,774,238
Treasury Stock
Increase (Decrease) in Stockholders' Equity (in shares)
Beginning balance, treasury shares (in shares)	(194,335,971)	(179,793,275)	(178,825,915)	(172,894,601)
Shares issued under ESPP (in shares)		142,825	117,392	131,469
Shares issued from LTIP (in shares)		0	0	0
Share repurchases (in shares)		(14,685,521)	(1,084,752)	(6,062,783)
Ending balance, treasury shares (in shares)		(194,335,971)	(179,793,275)	(178,825,915)
Treasury Stock \| Subsequent Event
Increase (Decrease) in Stockholders' Equity (in shares)
Shares issued from LTIP (in shares)	0
Ending balance, treasury shares (in shares)	(194,335,971)

Capital Structure - Common Stock (Details) - USD ($)		1 Months Ended	3 Months Ended		12 Months Ended
Capital Structure - Common Stock (Details) - USD ($)	Jan. 20, 2023	Dec. 31, 2021	Mar. 31, 2020	Dec. 31, 2019	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Equity, Class of Treasury Stock [Line Items]
Quarterly dividends per share (usd per share)						$ 0.350	$ 0.325	$ 0.30
Dividends paid per share (in usd per share)						1.40	1.30	$ 1.20
Common stock, dividends, proposed annual amount, per share (usd per share)			$ 1.20			$ 1.40	$ 1.30		$ 0.12
Common stock, annual dividends increase, percentage						8.00%	8.00%
Eligible compensation withholding, minimum, percentage						1.00%
Eligible compensation withholding, maximum, percentage						10.00%
Market value on offering date percentage						95.00%
Exercise price as a percentage of fair value (as a percent)						95.00%
Treasury stock reserved for issuance under the ESPP (in shares)		2,493,374					2,493,374
Shares repurchased (in shares)						14,685,521	1,084,752	6,062,783
2021 Capital Allocation Plan
Equity, Class of Treasury Stock [Line Items]
Stock repurchase program, authorized amount		$ 1,000,000,000					$ 1,000,000,000
Shares repurchased (in shares)		44,000,000				601,000,000
Stock repurchase program, remaining amount						$ 355,000,000
Subsequent Event
Equity, Class of Treasury Stock [Line Items]
Dividends per common share (in usd per share)	$ 0.3775
Scenario, Plan \| Subsequent Event
Equity, Class of Treasury Stock [Line Items]
Common stock, dividends, proposed annual amount, per share (usd per share)	$ 1.51				$ 1.51
Common stock, annual dividends increase, percentage					8.00%
Scenario, Plan \| Subsequent Event \| 2023 Capital Allocation Plan
Equity, Class of Treasury Stock [Line Items]
Stock repurchase program, authorized amount					$ 600,000,000
Capital allocation plan, return of cash available to shareholders, percentage					50.00%
Minimum
Equity, Class of Treasury Stock [Line Items]
Annual dividend growth rate, percentage				700.00%
Maximum
Equity, Class of Treasury Stock [Line Items]
Annual dividend growth rate, percentage				9.00%
Long-term incentive plans
Equity, Class of Treasury Stock [Line Items]
Long-term incentive plans (in shares)						14,022,916

Capital Structure - Summary of Changes in Shares Repurchased (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)	14,685,521	1,084,752	6,062,783
Repurchases
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)			6,062,783
Amounts paid for shares and share equivalents purchased (in millions)			$ 197
Equivalent shares purchased in lieu of tax withholding on equity compensation issuances
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)	151,241	249,013	711,248
Average price paid per share (in shares)	$ 42.74	$ 37.50	$ 38.23
Amounts paid for shares and share equivalents purchased (in millions)	$ 6	$ 9	$ 27
Other repurchases
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)	14,685,521	1,084,752
Amounts paid for shares and share equivalents purchased (in millions)	$ 595	$ 44
Accrued stock repurchases		$ 5
Capital Allocation Plan
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)	14,836,762	1,333,765	6,774,031
Average price paid per share (in shares)	$ 40.50	$ 40.22	$ 33.05
Amounts paid for shares and share equivalents purchased (in millions)	$ 601	$ 53	$ 224

Investments Accounted for by the Equity Method and Variable Interest Entities - Entities Not Consolidated (Details) - USD ($) $ in Millions	Jun. 01, 2022	Sep. 14, 2022
Watson Facility
Investments Accounted for by the Equity Method
Ownership percentage	49.00%
Proceeds from sale of investment	$ 59
Petra Nova Parish Holdings
Investments Accounted for by the Equity Method
Ownership percentage		50.00%

Investments Accounted for by the Equity Method and Variable Interest Entities - Summary of Equity Method Investments and Undistributed Earnings (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Investments Accounted for by the Equity Method
Equity investments in affiliates	$ 133	$ 157
Undistributed earnings from equity investment	$ 42	$ 33
Gladstone
Investments Accounted for by the Equity Method
Economic interest in equity method investments (as a percent)	37.50%
Equity investments in affiliates	$ 128
Ivanpah Master Holdings, LLC(a)
Investments Accounted for by the Equity Method
Economic interest in equity method investments (as a percent)	54.50%
Equity investments in affiliates	$ 0
Midway-Sunset Cogeneration Company
Investments Accounted for by the Equity Method
Economic interest in equity method investments (as a percent)	50.00%
Equity investments in affiliates	$ 5

Investments Accounted for by the Equity Method and Variable Interest Entities - Other Equity Investments (Details) $ in Millions	Dec. 31, 2022 USD ($) MW	Dec. 31, 2021 USD ($)
Schedule of Equity Method Investments [Line Items]
Generation capacity (in MW) \| MW	16
Equity investments in affiliates \| $	$ 133	$ 157
Gladstone
Schedule of Equity Method Investments [Line Items]
Ownership percentage	37.50%
Generation capacity (in MW) \| MW	1,613
Equity investments in affiliates \| $	$ 128

Investments Accounted for by the Equity Method and Variable Interest Entities - Summarized Financial Information (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Schedule of Equity Method Investments [Line Items]
Current liabilities	$ 12,982	$ 7,915
Variable Interest Entity, Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Accounts receivable and Other current assets	2,108	939
Current liabilities	152	78
Net assets	$ 1,956	$ 861

- Definition

Total obligations incurred as part of normal operations that are expected to be paid during the following twelve months or within one business cycle, if longer.

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Income Per Share - Reconciliation of Basic and Diluted EPS (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Basic income per share attributable to NRG Energy, Inc;
Net income attributable to NRG Energy, Inc. common stockholders	$ 1,221	$ 2,187	$ 510
Weighted average number of common shares outstanding — basic (in shares)	236,000,000	245,000,000	245,000,000
Diluted income per share attributable to NRG Energy, Inc;	$ 5.17	$ 8.93	$ 2.08
Diluted income per share attributable to NRG Energy, Inc;
Net income attributable to NRG Energy, Inc. common stockholders	$ 1,221	$ 2,187	$ 510
Weighted average number of common shares outstanding — basic (in shares)	236,000,000	245,000,000	245,000,000
Incremental shares attributable to the issuance of equity compensation (treasury stock method) (in shares)	0	0	1,000,000
Weighted average number of common shares outstanding- dilutive (in shares)	236,000,000	245,000,000	246,000,000
Income per weighted average common share — diluted (in usd per share)	$ 5.17	$ 8.93	$ 2.07

- Definition

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

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The amount of net income (loss) for the period available to each share of common stock or common unit outstanding during the reporting period and to each share or unit that would have been outstanding assuming the issuance of common shares or units for all dilutive potential common shares or units outstanding during the reporting period.

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+ Details

Segment Reporting (Details) - USD ($) $ in Millions	3 Months Ended			12 Months Ended
Segment Reporting (Details) - USD ($) $ in Millions	Sep. 30, 2022	Jun. 30, 2022	Dec. 31, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Statement
Revenues				$ 31,543	$ 26,989	$ 9,093
Operating expenses				28,737	22,566	7,481
Depreciation and amortization				634	785	435
Impairment losses				206	544	75
Total operating cost and expenses				29,577	23,895	7,991
Gain on sale of assets				52	247	3
Operating income				2,018	3,341	1,105
Equity in (losses)/earnings of unconsolidated affiliates				6	17	17
Impairment losses on investments				0	0	(18)
Other income, net				56	63	67
Loss on debt extinguishment				0	(77)	(9)
Interest expense				(417)	(485)	(401)
Income Before Income Taxes				1,663	2,859	761
Income tax expense (benefit)				442	672	251
Net income (loss)				1,221	2,187	510
Balance sheet
Equity investments in affiliates			$ 157	133	157
Capital expenditures			269	367	269
Goodwill			1,795	1,650	1,795	579
Total assets			23,182	29,146	23,182
Corporate
Income Statement
Revenues				0	0	0
Operating expenses				86	141	57
Depreciation and amortization				31	28	34
Impairment losses				0	0	0
Total operating cost and expenses				117	169	91
Gain on sale of assets				(3)	211	5
Operating income				(120)	42	(86)
Equity in (losses)/earnings of unconsolidated affiliates				0	0	0
Impairment losses on investments						0
Other income, net				54	59	41
Loss on debt extinguishment					(77)	0
Interest expense				(400)	(469)	(384)
Income Before Income Taxes				(466)	(445)	(429)
Income tax expense (benefit)				384	653	250
Net income (loss)				(850)	(1,098)	(679)
Balance sheet
Equity investments in affiliates			0	0	0
Capital expenditures			45	50	45
Goodwill			0	0	0
Total assets			19,051	35,780	19,051
Eliminations
Income Statement
Revenues				17	10	(4)
Operating expenses				17	10	(4)
Depreciation and amortization				0	0	0
Impairment losses				0	0	0
Total operating cost and expenses				17	10	(4)
Gain on sale of assets				0	0	0
Operating income				0	0	0
Equity in (losses)/earnings of unconsolidated affiliates				0	0	0
Impairment losses on investments						0
Other income, net				(16)	(14)	0
Loss on debt extinguishment					0	0
Interest expense				16	14	0
Income Before Income Taxes				0	0	0
Income tax expense (benefit)				0	0	0
Net income (loss)				0	0	0
Balance sheet
Equity investments in affiliates			0	0	0
Capital expenditures			0	0	0
Goodwill			0	0	0
Total assets			(26,458)	(45,774)	(26,458)
Texas
Balance sheet
Goodwill			716	710	716	289
Texas \| Operating Segments
Income Statement
Revenues				10,057	10,295	6,312
Operating expenses				8,495	8,692	5,251
Depreciation and amortization				310	336	233
Impairment losses				0	0	14
Total operating cost and expenses				8,805	9,028	5,498
Gain on sale of assets				10	19	0
Operating income				1,262	1,286	814
Equity in (losses)/earnings of unconsolidated affiliates				(2)	(3)	(12)
Impairment losses on investments						(18)
Other income, net				5	8	11
Loss on debt extinguishment					0	0
Interest expense				0	(1)	0
Income Before Income Taxes				1,265	1,290	795
Income tax expense (benefit)				0	0	0
Net income (loss)				1,265	1,290	795
Balance sheet
Equity investments in affiliates			0	0	0
Capital expenditures			153	273	153
Goodwill			716	710	716
Total assets			12,271	11,475	12,271
Texas \| Eliminations
Income Statement
Revenues				(4)	(5)	(6)
East
Income Statement
Impairment losses	$ 43	$ 20	16	13
Balance sheet
Goodwill			853	723	853	240
East \| Operating Segments
Income Statement
Revenues				16,763	13,025	2,249
Operating expenses				16,031	10,256	1,755
Depreciation and amortization				208	333	132
Impairment losses				206	535	0
Total operating cost and expenses				16,445	11,124	1,887
Gain on sale of assets				0	0	0
Operating income				318	1,901	362
Equity in (losses)/earnings of unconsolidated affiliates				0	0	0
Impairment losses on investments						0
Other income, net				10	7	7
Loss on debt extinguishment					0	(4)
Interest expense				(1)	(1)	(14)
Income Before Income Taxes				327	1,907	351
Income tax expense (benefit)				1	0	(1)
Net income (loss)				326	1,907	352
Balance sheet
Equity investments in affiliates			0	0	0
Capital expenditures			50	7	50
Goodwill			853	723	853
Total assets			13,645	19,526	13,645
East \| Eliminations
Income Statement
Revenues				26	18	6
West/Services/Other
Balance sheet
Goodwill			226	217	226	50
West/Services/Other \| Operating Segments
Income Statement
Revenues				4,706	3,659	536
Operating expenses				4,108	3,467	422
Depreciation and amortization				85	88	36
Impairment losses				0	9	61
Total operating cost and expenses				4,193	3,564	519
Gain on sale of assets				45	17	(2)
Operating income				558	112	15
Equity in (losses)/earnings of unconsolidated affiliates				8	20	29
Impairment losses on investments						0
Other income, net				3	3	8
Loss on debt extinguishment					0	(5)
Interest expense				(32)	(28)	(3)
Income Before Income Taxes				537	107	44
Income tax expense (benefit)				57	19	2
Net income (loss)				480	88	42
Balance sheet
Equity investments in affiliates			157	133	157
Capital expenditures			21	37	21
Goodwill			226	217	226
Total assets			$ 4,673	8,139	4,673
West/Services/Other \| Eliminations
Income Statement
Revenues				$ (5)	$ (3)	$ (4)

Income Taxes - Income Tax Provision (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Current
U.S. Federal	$ 3	$ 0	$ 0
State	65	48	22
Foreign	3	3	4
Total — current	71	51	26
Deferred
U.S. Federal	258	569	168
State	59	36	60
Foreign	54	16	(3)
Total — deferred	371	621	225
Total income tax expense	442	672	251
Domestic and foreign components of income from continuing operations before income tax expense
U.S.	1,436	2,759	749
Foreign	227	100	12
Income Before Income Taxes	1,663	2,859	761
Reconciliation of the U.S. federal statutory rate to NRG's effective rate from continuing operations
Income before income taxes	1,663	2,859	761
Tax at federal statutory tax rate	349	600	160
Foreign operations	7	(3)	0
State taxes	69	111	18
Permanent differences	17	8	8
Changes in valuation allowance	(3)	(29)	24
Deferred impact of state tax rate changes	14	(10)	2
Recognition of uncertain tax benefits	8	(10)	3
Carbon capture tax credits	(19)	0	0
Return to provision adjustments	0	5	36
Total income tax expense	$ 442	$ 672	$ 251
Effective income tax rate (as a percent)	26.60%	23.50%	33.00%

Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Deferred tax assets:
Deferred compensation, accrued vacation and other reserves	$ 93	$ 114
Difference between book and tax basis of property	399	436
Pension and other postretirement benefits	62	65
Equity compensation	8	7
Allowance for credit losses	33	168
U.S. Federal net operating loss carryforwards	1,717	1,773
Foreign net operating loss carryforwards	104	112
State net operating loss carryforwards	315	328
Federal and state tax credit carryforwards	393	384
Federal benefit on state uncertain tax positions	5	3
Interest disallowance carryforward per §163(j) of the Tax Act	65	6
Inventory obsolescence	10	9
U.S. capital loss	15	0
Other	22	15
Total deferred tax assets	3,241	3,420
Deferred tax liabilities:
Emissions allowances	19	20
Derivatives, net	874	591
Goodwill	26	40
Intangibles amortization (excluding goodwill)	269	363
Equity method investments	82	62
Convertible Debt	0	14
Total deferred tax liabilities	1,270	1,090
Total deferred tax assets less deferred tax liabilities	1,971	2,330
Valuation allowance	(224)	(248)
Net deferred tax asset	1,747	2,082
NRG's net deferred tax position
Deferred tax asset	1,881	2,155
Deferred tax liability	(134)	(73)
Net deferred tax asset	$ 1,747	$ 2,082

Income Taxes - Narrative for Deferred Tax Assets and Valuation Allowance, Taxes Receivable and Payable (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Taxes receivable and payable
Deferred tax asset	$ 1,747	$ 2,082
Deferred tax asset, net (before valuation allowance)	1,971	2,330
Valuation allowance	224	$ 248
Current net federal tax receivable	5
Federal Tax Authority
Taxes receivable and payable
Operating loss carryforwards	1,700
State and Local Jurisdiction
Taxes receivable and payable
Operating loss carryforwards	315
Foreign Tax Authority
Taxes receivable and payable
Operating loss carryforwards	104
Current taxes receivable	$ 13

Income Taxes - Reconciliation of Uncertain Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Uncertain tax benefits
Uncertain tax benefits	$ 22	$ 13	$ 15
Liability for uncertainty in income taxes, noncurrent	24	14
Unrecognized tax benefits, income tax penalties expense	1		1
Accrued interest and penalties related to unrecognized tax benefits	2	1
Uncertain tax benefits reconciliation
Balance as of January 1	13	15
Increase due to current year positions	9	4
Increase due to acquired balance from Direct Energy	0	9
Settlements, payments and statute closure	0	(15)
Uncertain tax benefits as of December 31	$ 22	$ 13	$ 15

Stock-Based Compensation - Long-Term Incentive Plan (Details) - NRG LTIP - shares	Apr. 27, 2017	Dec. 31, 2022	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Increase in the number of shares available for issuance (in shares)	3,000,000
Number of shares authorized for issuance under plan (in shares)		25,000,000	25,000,000
Number of shares available for grant under plan (in shares)		8,179,771	8,871,874

Stock-Based Compensation - Restricted Stock Units (RSUs) (Details) - RSUs - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Stock-Based Compensation
Award vesting period	3 years
Units
Non-vested at beginning of period (in shares)	669,952
Granted (in shares)	530,565
Forfeited (in shares)	(43,601)
Vested (in shares)	(299,999)
Non-vested at end of period (in shares)	856,917	669,952
Weighted Average Grant Date Fair Value per Unit
Non-vested at beginning of period (in usd per share)	$ 38.69
Granted (in usd per share)	41.26	$ 39.00	$ 38.05
Forfeited (in usd per share)	41.09
Vested (in usd per share)	38.36
Non-vested at end of period (in usd per share)	$ 40.25	$ 38.69
Vested in period, fair value	$ 10	$ 12	$ 17
Weighted average grant date fair value (in usd per share)	$ 41.26	$ 39.00	$ 38.05

Stock-Based Compensation - Deferred Stock Units (DSUs) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Stock-Based Compensation
Participant right to receive common stock at end of deferral period (in shares)	1
DSUs
Units
Balance outstanding at the beginning of the period (in shares)	384,128
Granted (in shares)	52,865
Converted to Common Stock (in shares)	(18,979)
Balance outstanding at the end of the period (in shares)	418,014	384,128
Weighted Average Grant Date Fair Value per Unit
Balance outstanding at the beginning of the period, (in usd per share)	$ 26.11
Granted (in usd per share)	45.49	$ 32.27	$ 35.59
Vested (in usd per share)	39.27
Balance outstanding at the end of the period (in usd per share)	$ 27.63	$ 26.11
Aggregate intrinsic value for DSUs outstanding	$ 13,000,000	$ 17,000,000	$ 13,000,000
Aggregate intrinsic values for DSUs converted to common stock during the period	$ 1,000,000	$ 1,000,000	$ 2,000,000
Weighted average grant date fair value (in usd per share)	$ 45.49	$ 32.27	$ 35.59

Stock -Based Compensation - Performance Stock Units, RPSUs Plan Description (Details) - RPSUs	12 Months Ended
	Dec. 31, 2022
Stock-Based Compensation
Award vesting period	3 years
Share-based Payment Arrangement, Tranche One
Stock-Based Compensation
Award vesting right, percentage	0.00%
Share-based Payment Arrangement, Tranche Two
Stock-Based Compensation
Award vesting right, percentage	25.00%
Share-based Payment Arrangement, Tranche Three
Stock-Based Compensation
Award vesting right, percentage	100.00%
Share-based Payment Arrangement, Tranche Four
Stock-Based Compensation
Award vesting right, percentage	15.00%
Share-based Payment Arrangement, Tranche Five
Stock-Based Compensation
Award vesting right, percentage	200.00%

Stock-Based Compensation - Performance Stock Units (Details) - RPSUs - $ / shares	1 Months Ended	12 Months Ended
	Sep. 30, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Units
Non-vested at beginning of period (in shares)		730,505
Granted (in shares)	60,815	291,852
Forfeited (in shares)		(54,392)
Vested (in shares)		(172,630)
Non-vested at end of period (in shares)		795,335	730,505
Weighted Average Grant-Date Fair Value per Unit
Non-vested at beginning of period (in usd per share)		$ 47.40
Granted (in usd per share)		57.41	$ 46.78	$ 23.75
Forfeited (in usd per share)		46.68
Vested (in usd per share)		45.77
Non-vested at end of period (in usd per share)		$ 50.23	$ 47.40
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Expected volatility	37.38%	37.54%	34.05%	30.15%
Expected term (in years)		3 years	3 years	3 years
Risk free rate	0.42%	0.97%	0.17%	1.58%

Stock-Based Compensation - Non-Qualified Stock Options (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Stock-Based Compensation
Options exercised (in shares)	14,477
Compensation expense	$ 34,000,000	$ 27,000,000	$ 27,000,000
NQSOs
Stock-Based Compensation
Shares granted during the period (in shares)	0	0	0
Outstanding at the beginning of the period (in shares)		17,870
Options expired (in shares)	3,393
Compensation expense	$ 0	$ 0	$ 0

Stock-Based Compensation - Supplemental Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Stock-Based Compensation
Minimum tax withholdings	$ 6	$ 9	$ 27
Compensation Expense	34	27	27
Tax detriment/(benefit) recognized	3	2	(9)
Unrecognized Total Cost	37
RSUs
Stock-Based Compensation
Compensation Expense	15	9	9
Unrecognized Total Cost	$ 17
Weighted Average Recognition Period Remaining (In years)	1 year 9 months
Award vesting period	3 years
DSUs
Stock-Based Compensation
Compensation Expense	$ 2	2	2
Unrecognized Total Cost	$ 0
Weighted Average Recognition Period Remaining (In years)	0 years
RPSUs
Stock-Based Compensation
Compensation Expense	$ 11	9	10
Unrecognized Total Cost	$ 13
Weighted Average Recognition Period Remaining (In years)	1 year 1 month 28 days
Award vesting period	3 years
PRSUs
Stock-Based Compensation
Compensation Expense	$ 6	$ 7	$ 6
Unrecognized Total Cost	$ 7
Weighted Average Recognition Period Remaining (In years)	1 year 5 months 12 days
Award vesting period	3 years

Related Party Transactions - Summary of Material Related Party Transactions With Third Party Affiliates (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Revenues from Related Parties Included in Revenues	$ 52	$ 49	$ 52
Gladstone
Related Party Transaction [Line Items]
Revenues from Related Parties Included in Revenues	4	4	4
Ivanpah
Related Party Transaction [Line Items]
Revenues from Related Parties Included in Revenues	42	39	43
Midway-Sunset
Related Party Transaction [Line Items]
Revenues from Related Parties Included in Revenues	$ 6	$ 6	$ 5

- Definition

Amount of revenue, fees and commissions earned from transactions between (a) a parent company and its subsidiaries; (b) subsidiaries of a common parent; (c) an entity and trusts for the benefit of employees, for example, but not limited to, pension and profit-sharing trusts that are managed by or under the trusteeship of the entity's management; (d) an entity and its principal, owners, management, or members of their immediate families; and (e) affiliates.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1B
-Subparagraph (SX 210.13-02(a)(4)(iv))
-URI https://asc.fasb.org/extlink&oid=126975872&loc=SL124442552-122756

Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 946
-SubTopic 220
-Section S99
-Paragraph 1
-Subparagraph (SX 210.6-07.1(c))
-URI https://asc.fasb.org/extlink&oid=120401555&loc=SL114874292-224272

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1A
-Subparagraph (SX 210.13-01(a)(4)(iii)(B))
-URI https://asc.fasb.org/extlink&oid=126975872&loc=SL124442526-122756

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1B
-Subparagraph (SX 210.13-02(a)(4)(iii)(C))
-URI https://asc.fasb.org/extlink&oid=126975872&loc=SL124442552-122756

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1A
-Subparagraph (SX 210.13-01(a)(5))
-URI https://asc.fasb.org/extlink&oid=126975872&loc=SL124442526-122756

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1B
-Subparagraph (SX 210.13-02(a)(5))
-URI https://asc.fasb.org/extlink&oid=126975872&loc=SL124442552-122756

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1A
-Subparagraph (SX 210.13-01(a)(4)(iv))
-URI https://asc.fasb.org/extlink&oid=126975872&loc=SL124442526-122756

Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03.1(e))
-URI https://asc.fasb.org/extlink&oid=126953954&loc=SL114868664-224227

+ Details

Commitments and Contingencies - Certain Fuel, Transportation and Purchased Energy Commitments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Coal, Gas and Transportation Commitments
Commitments and Contingencies
Purchases under coal, gas and transportation arrangement	$ 736	$ 584	$ 479
Minimum purchase commitment
2023	110
2024	71
2025	83
2026	54
2027	78
Thereafter	56
Total	452
Purchases under energy contracts	736	584	479
Renewable Purchased Power Agreements
Commitments and Contingencies
Purchases under coal, gas and transportation arrangement	18,800	12,800	1,800
Minimum purchase commitment
2023	908
2024	1,050
2025	662
2026	396
2027	296
Thereafter	987
Total	4,299
Purchases under energy contracts	18,800	$ 12,800	$ 1,800
Short-term commitments	$ 1,500

Commitments and Contingencies - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) nuclearReactor assessment case	Oct. 31, 2021 facility	Jun. 30, 2019 facility
Loss Contingencies [Line Items]
Nuclear insurance liability limit per incident	$ 13,700
Required nuclear liability insurance	450
Nuclear financial protection pool mandated by the Price-Anderson Act	13,200
Maximum assessment mandated by Price-Anderson Act per nuclear reactor for a nuclear incident	$ 138
Maximum assessment, administrative fee (as percent)	5.00%
Maximum assessment payment mandated by Price-Anderson Act for a nuclear incident	$ 21
Maximum assessment	44.00%
Nuclear operator maximum annual assessment	$ 9
Maximum liability per nuclear incident	61
Mutual property insurance additional blanket policy property coverage	$ 1,300
Number of nuclear reactors with shared single limit blanket coverage \| nuclearReactor	2
Nuclear property insurance coverage limit per individual insured	$ 1,500
Lost revenue insurance maximum weekly recovery	$ 3
Insurance coverage, waiting period	56 days
Accidental outage weekly recovery limit for loss revenues from a nuclear industry mutual insurance company in the event of insurable loss	$ 2
The number of months a nuclear industry mutual insurance company will respond to retrospective premium adjustments	24 months
Number of years board of directors of industry mutual insurance company can adjust policy after policy expires	6 years
Number of facilities \| facility		2
Sierra Club Et Al V. Midwest Generation L L C
Loss Contingencies [Line Items]
Number of facilities \| facility			4
Direct Energy vs. Stanley, Forte, Schafer and Lane
Loss Contingencies [Line Items]
Number of class action lawsuits \| case	4
Direct Energy vs. Burk and Dickson Litigation
Loss Contingencies [Line Items]
Number of class action lawsuits \| case	2
High
Loss Contingencies [Line Items]
Multiplier that the industry mutual insurance company may assess against insureds premium \| assessment	10
Low
Loss Contingencies [Line Items]
Multiplier that the industry mutual insurance company may assess against insureds premium \| assessment	6
Nuclear Event
Loss Contingencies [Line Items]
Total nuclear property insurance coverage	$ 2,800
Lost revenue insurance maximum weekly recovery	274
Accidental outage weekly recovery limit for loss revenues from a nuclear industry mutual insurance company in the event of insurable loss	216
Non-nuclear Event
Loss Contingencies [Line Items]
Total nuclear property insurance coverage	1,000
Lost revenue insurance maximum weekly recovery	183
Accidental outage weekly recovery limit for loss revenues from a nuclear industry mutual insurance company in the event of insurable loss	$ 144

Environmental Matters (Details) $ in Millions	Dec. 31, 2022 USD ($)	Oct. 31, 2021 facility
Environmental Remediation Obligations [Abstract]
Environmental proceedings, disclosure threshold \| $	$ 1
Number of facilities \| facility		2

Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
Cash Flow Information (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Supplemental Cash Flow Information [Abstract]
Interest paid, net of amount capitalized	$ 383	$ 433	$ 340
Income taxes paid, net of refunds	66	32	24
Decreases to fixed assets for accrued capital expenditures	$ (68)	$ (16)	$ (6)

Guarantees - Schedule of Maximum Potential Exposure (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Guarantor Obligations
Under 1 Year	$ 5,481
1-3 Years	25
3-5 Years	34
Over 5 Years	95
Guarantees by Remaining Maturity, Total	5,635	$ 4,602
Letters of credit and surety bonds
Guarantor Obligations
Under 1 Year	5,211
1-3 Years	0
3-5 Years	0
Over 5 Years	0
Guarantees by Remaining Maturity, Total	5,211	4,095
Asset sales guarantee obligations
Guarantor Obligations
Under 1 Year	270
1-3 Years	25
3-5 Years	34
Over 5 Years	80
Guarantees by Remaining Maturity, Total	409	414
Other guarantees
Guarantor Obligations
Under 1 Year	0
1-3 Years	0
3-5 Years	0
Over 5 Years	15
Guarantees by Remaining Maturity, Total	$ 15	$ 93

Guarantees - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
Guarantees - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Guarantor Obligations
Guarantee obligation	$ 5,635	$ 4,602
Letters of credit and surety bonds
Guarantor Obligations
Guarantee obligation	$ 5,211	4,095
Letters of credit and surety bonds, maximum expiration period (in years)	1 year
Asset sales guarantee obligations
Guarantor Obligations
Guarantee obligation	$ 409	$ 414
California property tax indemnity	$ 141

Jointly Owned Plants (Details) $ in Millions	Dec. 31, 2022 USD ($)
South Texas Project Units 1 and 2, Bay City, TX
Jointly Owned Utility Plant Interests
Ownership Interest (as a percent)	44.00%
Property, Plant & Equipment	$ 478
Accumulated Depreciation	(235)
Construction in Progress	$ 7
Cedar Bayou Unit 4, Baytown, TX
Jointly Owned Utility Plant Interests
Ownership Interest (as a percent)	50.00%
Property, Plant & Equipment	$ 229
Accumulated Depreciation	(118)
Construction in Progress	$ 7

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Allowance for credit losses, deducted from accounts receivable
Income tax valuation allowance, deducted from deferred tax assets
Balance at Beginning of Period	$ 683	$ 67	$ 43
Charged to Costs and Expenses	11	698	108
Charged to Other Accounts	0	112	0
Deductions	(561)	(194)	(84)
Balance at End of Period	133	683	67
Income tax valuation allowance, deducted from deferred tax assets
Income tax valuation allowance, deducted from deferred tax assets
Balance at Beginning of Period	248	266	242
Charged to Costs and Expenses	(20)	(29)	24
Charged to Other Accounts	(4)	11	0
Deductions	0	0	0
Balance at End of Period	$ 224	$ 248	$ 266