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Schedule I - Condensed Financial Statements - B/S (Details) - USD ($) $ in Millions	Dec. 31, 2025	Sep. 30, 2025	Jun. 30, 2025	Mar. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Current Assets
Cash and cash equivalents	$ 231				$ 332
Other Assets
Total Assets	16,444				14,320
Current Liabilities
Other non-current liabilities	389				320
Total Liabilities	10,416				8,679
Commitments and Contingencies
Members’ Equity
Contributed capital	641				911
Retained earnings	875	$ 1,016	$ 761	$ 802	894
Accumulated other comprehensive (loss) income	(10)				7
Total Members’ Equity	5,925				5,641	$ 5,105	$ 4,160
Total Liabilities and Members’ Equity	16,444				14,320
Affiliated Entity
Current Assets
Accounts Receivable, after Allowance for Credit Loss, Current	1				0
Other Liabilities
Accounts payable — affiliates	32				35
Clearway Energy LLC
Current Assets
Cash and cash equivalents	37				137
Other current assets	0				1
Other Assets
Investment in consolidated subsidiaries	1,470				1,679
Total Assets	1,508				1,817
Current Liabilities
Other non-current liabilities	1				1
Total Liabilities	2				5
Commitments and Contingencies
Members’ Equity
Contributed capital	641				911
Retained earnings	875				894
Accumulated other comprehensive (loss) income	(10)				7
Total Members’ Equity	1,506				1,812
Total Liabilities and Members’ Equity	1,508				1,817
Clearway Energy LLC \| Affiliated Entity
Current Assets
Accounts Receivable, after Allowance for Credit Loss, Current	1				0
Other Liabilities
Accounts payable — affiliates	$ 1				$ 4

Leases - Lessor - Schedule of Minimum Future Rent Payments Under the Operating Leases (Details) $ in Millions	Dec. 31, 2025 USD ($)
Leases [Abstract]
2026	$ 214
2027	215
2028	213
2029	211
2030	212
Thereafter	1,918
Total lease payments	$ 2,983

Summary of Significant Accounting Policies -Schedule of Redeemable Noncontrolling Interest (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2025	Jun. 30, 2025	Mar. 31, 2025	Jun. 30, 2025	Sep. 30, 2025	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Increase (Decrease) in Temporary Equity [Roll Forward]
Non-cash distributions to redeemable noncontrolling interests						$ 4	$ 1	$ 7
Comprehensive income (loss) attributable to redeemable noncontrolling interests	$ (316)	$ (46)	$ (101)	$ (147)	$ (463)	(557)	(233)	(163)
Redeemable Noncontrolling Interest
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance			$ 0	$ 0	$ 0	0	1
Cash distributions to redeemable noncontrolling interests							(2)
Cash contributions to redeemable noncontrolling interests, net of distributions						335
Non-cash distributions to redeemable noncontrolling interests						(12)
Comprehensive income (loss) attributable to redeemable noncontrolling interests						(220)	13
Repurchase of redeemable noncontrolling interest							(12)
Ending balance						$ 103	$ 0	$ 1

- Definition

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

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+ Details

- Definition

Carrying amount, attributable to parent and noncontrolling interests, of an entity's issued and outstanding stock which is not included within permanent equity. Temporary equity is a security with redemption features that are outside the control of the issuer, is not classified as an asset or liability in conformity with GAAP, and is not mandatorily redeemable. Includes any type of security that is redeemable at a fixed or determinable price or on a fixed or determinable date or dates, is redeemable at the option of the holder, or has conditions for redemption which are not solely within the control of the issuer. Includes stock with a put option held by an ESOP and stock redeemable by a holder only in the event of a change in control of the issuer.

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Nature of Business	12 Months Ended
Nature of Business	Dec. 31, 2025
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	Nature of Business Clearway Energy LLC, together with its consolidated subsidiaries, or the Company, is an energy infrastructure investor with a focus on investments in clean energy and owner of modern, sustainable and long-term contracted assets across North America. The Company is sponsored by Clearway Energy Group LLC, or CEG. The Company is one of the largest owners of clean energy generation assets in the U.S. The Company’s portfolio comprises approximately 12.9 GW of gross capacity in 27 states, including approximately 10.1 GW of wind, solar and battery energy storage systems, or BESS, and approximately 2.8 GW of dispatchable combustion-based power generation assets included in the Flexible Generation segment that provide critical grid reliability services. Through this environmentally-sound, diversified and primarily contracted portfolio, the Company endeavors to provide its unit holders with stable and growing distributions. The majority of the Company’s revenues are derived from long-term contractual arrangements for the output or capacity from these assets. Clearway Energy, Inc., or Clearway, Inc., consolidates the results of the Company through its controlling interest, with CEG’s interest shown as contributed capital in the Company’s consolidated financial statements. The holders of Clearway, Inc.’s outstanding shares of Class A and Class C common stock are entitled to dividends as declared. CEG receives its distributions from the Company through its ownership of the Company’s Class B and Class D units. From time to time, CEG may also hold shares of Clearway, Inc.’s Class A and/or Class C common stock. As of December 31, 2025, Clearway, Inc. owned 58.62% of the economic interests of the Company, with CEG owning 41.38% of the economic interests of the Company. For further discussion, see Note 11, Members’ Equity. The diagram below represents a summarized structure of the Company as of December 31, 2025:

Intangible Assets - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Goodwill and Intangible Assets Disclosure [Abstract]
Amortization expense	$ 189	$ 184	$ 186
Contract amortization expense	183	$ 178	$ 181
Expected amortization, year one	200
Expected amortization, year two	200
Expected amortization, year three	200
Expected amortization, year four	200
Expected amortization, year five	$ 200

- Definition

The aggregate expense charged against earnings to allocate the cost of intangible assets (nonphysical assets not used in production) in a systematic and rational manner to the periods expected to benefit from such assets.

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+ Details

Long-term Debt - Schedule of Swaps Related to the Company's Facility Level Debt (Details) - Interest Rate Swap $ in Millions	Dec. 31, 2025 USD ($)
Debt Instrument [Line Items]
Notional Amount at December 31, 2025 (In millions)	$ 4,080
Avra Valley
Debt Instrument [Line Items]
% of Principal	85.00%
Fixed Interest Rate	2.20%
Notional Amount at December 31, 2025 (In millions)	$ 23
Alta Wind Asset Management
Debt Instrument [Line Items]
% of Principal	100.00%
Fixed Interest Rate	2.22%
Notional Amount at December 31, 2025 (In millions)	$ 8
Buckthorn Solar
Debt Instrument [Line Items]
% of Principal	100.00%
Fixed Interest Rate	2.63%
Notional Amount at December 31, 2025 (In millions)	$ 100
Capistrano Portfolio Holdco
Debt Instrument [Line Items]
% of Principal	100.00%
Notional Amount at December 31, 2025 (In millions)	$ 106
Carlsbad Energy Holdings
Debt Instrument [Line Items]
% of Principal	100.00%
Notional Amount at December 31, 2025 (In millions)	$ 46
Cedar Creek
Debt Instrument [Line Items]
% of Principal	100.00%
Fixed Interest Rate	3.02%
Notional Amount at December 31, 2025 (In millions)	$ 106
Cedro Hill
Debt Instrument [Line Items]
% of Principal	85.00%
Notional Amount at December 31, 2025 (In millions)	$ 77
Clearway Energy Operating (a)
Debt Instrument [Line Items]
% of Principal	0.00%
Notional Amount at December 31, 2025 (In millions)	$ 1,093
Daggett 1
Debt Instrument [Line Items]
% of Principal	95.00%
Notional Amount at December 31, 2025 (In millions)	$ 126
Daggett 2
Debt Instrument [Line Items]
% of Principal	87.00%
Notional Amount at December 31, 2025 (In millions)	$ 134
Daggett 3
Debt Instrument [Line Items]
% of Principal	84.00%
Notional Amount at December 31, 2025 (In millions)	$ 181
Honeycomb Portfolio
Debt Instrument [Line Items]
% of Principal	85.00%
Notional Amount at December 31, 2025 (In millions)	$ 694
Kansas South
Debt Instrument [Line Items]
% of Principal	75.00%
Fixed Interest Rate	1.93%
Notional Amount at December 31, 2025 (In millions)	$ 9
Luna Valley
Debt Instrument [Line Items]
% of Principal	95.00%
Notional Amount at December 31, 2025 (In millions)	$ 185
Mililani Class B
Debt Instrument [Line Items]
% of Principal	97.00%
Notional Amount at December 31, 2025 (In millions)	$ 85
NIMH Solar
Debt Instrument [Line Items]
% of Principal	100.00%
Fixed Interest Rate	3.25%
Notional Amount at December 31, 2025 (In millions)	$ 111
Oahu Solar
Debt Instrument [Line Items]
% of Principal	96.00%
Fixed Interest Rate	2.47%
Notional Amount at December 31, 2025 (In millions)	$ 72
Pine Forest
Debt Instrument [Line Items]
% of Principal	85.00%
Notional Amount at December 31, 2025 (In millions)	$ 88
Rosie Class B
Debt Instrument [Line Items]
% of Principal	93.00%
Notional Amount at December 31, 2025 (In millions)	$ 172
Rosie South
Debt Instrument [Line Items]
% of Principal	90.00%
Notional Amount at December 31, 2025 (In millions)	$ 206
South Trent
Debt Instrument [Line Items]
% of Principal	90.00%
Notional Amount at December 31, 2025 (In millions)	$ 13
TSN1 Class B
Debt Instrument [Line Items]
% of Principal	96.00%
Notional Amount at December 31, 2025 (In millions)	$ 163
Viento Funding II
Debt Instrument [Line Items]
% of Principal	90.00%
Fixed Interest Rate	2.53%
Notional Amount at December 31, 2025 (In millions)	$ 129
Tuolumne
Debt Instrument [Line Items]
% of Principal	100.00%
Notional Amount at December 31, 2025 (In millions)	$ 153

Fair Value of Financial Instruments

12 Months Ended

Dec. 31, 2025

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

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.

•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.

•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.

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.

For cash and cash equivalents, restricted cash, accounts receivable — trade, accounts receivable — affiliates, accounts payable — trade, accounts payable — affiliates and accrued expenses and other current liabilities, the carrying amounts approximate fair value because of the short-term maturity of those instruments and are classified as Level 1 within the fair value hierarchy.

The carrying amounts and estimated fair values of the Company’s recorded financial instruments not carried at fair market value or that do not approximate fair value are as follows:


	As of December 31, 2025				As of December 31, 2024
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(In millions)


Liabilities:
Long-term debt, including current portion — affiliate	$	6	$	6	$	—	$	—
Long-term debt, including current portion — external (a)	8,676		8,382		7,237		6,715

(a) Excludes net debt issuance 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 publicly-traded long-term debt is based on quoted market prices and is classified as Level 2 within the fair value hierarchy. The fair value of debt securities, non-publicly traded long-term debt and certain notes receivable of the Company are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments with equivalent credit quality and are classified as Level 3 within the fair value hierarchy. The following table presents the level within the fair value hierarchy for long-term debt, including current portion:


	As of December 31, 2025				As of December 31, 2024
	Level 2		Level 3		Level 2		Level 3
	(In millions)
Long-term debt, including current portion	$	2,038	$	6,350	$	1,922	$	4,793

Recurring Fair Value Measurements

The Company records its derivative assets and liabilities at fair market value on its consolidated balance sheets. The following table presents 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, 2025				As of December 31, 2024
	Fair Value (a)				Fair Value (a)
(In millions)	Level 2 (b)		Level 3		Level 2 (b)		Level 3
Derivative assets
Energy-related commodity contracts (c)	$	1	$	13	$	—	$	9
Interest rate contracts	142		—		166		—
Other financial instruments (d)	—		7		—		10
Total assets	$	143	$	20	$	166	$	19
Derivative liabilities
Energy-related commodity contracts (e)	$	—	$	333	$	—	$	371
Interest rate contracts	27		—		—		—
Total liabilities	$	27	$	333	$	—	$	371

(a) There were no derivative assets or liabilities classified as Level 1 as of December 31, 2025 and 2024.

(b) The Company’s interest rate swaps are measured at fair value using an income approach, which use readily observable inputs, such as forward interest rates (e.g., SOFR) and contractual terms to estimate fair value.

(c) Includes short-term backbone transportation service contracts classified as Level 2 and heat rate call option contracts classified as Level 3.

(d) Includes SREC contract.

(e) Includes long-term power commodity contracts and heat rate call option contracts classified as Level 3. As of December 31, 2025 and 2024, $330 million and $366 million, respectively, related to long-term power commodity contracts, and $3 million and $5 million, respectively, related to heat rate call option contracts.

The following table reconciles the beginning and ending balances for instruments that are recognized at fair value in the consolidated financial statements using significant unobservable inputs:


	Year ended December 31,
		2025		2024
(In millions)	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
Beginning balance		$	(352)	$	(317)
Settlements		83		(2)


Total losses for the period included in earnings		(44)		(33)
Ending balance		$	(313)	$	(352)
Change in unrealized losses included in earnings for derivatives and other financial instruments held as of December 31,		$	(44)	$	(33)

Derivative and Financial Instruments Fair Value Measurements

The Company’s contracts are non-exchange-traded and valued using prices provided by external sources. The Company uses quoted observable forward prices to value its energy-related commodity contracts, which includes long-term power commodity contracts and heat rate call option contracts. To the extent that observable forward prices are not available, the quoted prices reflect the average of the forward prices from the prior year, adjusted for inflation. As of December 31, 2025, contracts valued with prices provided by models and other valuation techniques make up 8% of derivative assets, 93% of derivative liabilities and 100% of other financial instruments.

The Company’s significant positions classified as Level 3 relate to physical and financial energy-related contracts, including long-term power commodity contracts and heat rate call option contracts executed in illiquid markets. The significant unobservable inputs used in developing fair value include illiquid power tenors and location pricing, which is derived by extrapolating pricing as a basis to liquid locations. The tenor pricing and basis spread are based on observable market data when available or derived from historic prices and forward market prices from similar observable markets when not available.

The following tables quantify the significant unobservable inputs used in developing the fair value of the Company’s Level 3 positions:


	December 31, 2025
	Fair Value						Input/Range
	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
	(In millions)
Long-term Power Commodity Contracts	$	—	$	330	Discounted Cash Flow	Forward Market Price ($ per MWh)	$	34.04	$	89.73	$	56.51
Heat Rate Call Option Commodity Contracts	13		3		Option Model	Forward Market Price ($ per MWh)	$	(29.26)	$	260.77	$	42.23
					Option Model	Forward Market Price ($ per MMBtu)	$	0.92	$	10.15	$	3.02
Other Financial Instruments	7		—		Discounted Cash Flow	Forecast annual generation levels of certain DG solar facilities	60,047 MWh		120,094 MWh		108,791 MWh


	December 31, 2024
	Fair Value						Input/Range
	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
	(In millions)
Long-term Power Commodity Contracts	$	—	$	366	Discounted Cash Flow	Forward Market Price ($ per MWh)	$	21.60	$	80.82	$	45.44
Heat Rate Call Option Commodity Contracts	9		5		Option Model	Forward Market Price ($ per MWh)	$	(19.30)	$	1,011.79	$	45.87
					Option Model	Forward Market Price $ (per MMBtu)	$	0.85	$	10.55	$	3.25
Other Financial Instruments	10		—		Discounted Cash Flow	Forecast annual generation levels of certain DG solar facilities	59,425 MWh		118,850 MWh		111,091 MWh

The following table provides the impact on the fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2025 and 2024:

Type

Significant Observable Input

Position

Change In Input

Impact on Fair Value Measurement

Energy-Related Commodity Contracts

Forward Market Price Power

Sell

Increase/(Decrease)

Lower/(Higher)

Energy-Related Commodity Contracts

Forward Market Price Gas

Sell

Increase/(Decrease)

Higher/(Lower)

Other Financial Instruments

Forecast Generation Levels

Sell

Increase/(Decrease)

Higher/(Lower)

The fair value of each contract is discounted using a risk-free interest rate. In addition, a credit reserve is applied to reflect credit risk, which is, for interest rate swaps, calculated based on credit default swaps using the bilateral method. For commodities, to the extent that the Net Exposure under a specific master agreement is an asset, the Company uses the counterparty’s default swap rate. If the Net Exposure under a specific master agreement is a liability, the Company uses a proxy of its own default swap rate. For interest rate swaps and commodities, the credit reserve is added to the discounted fair value to reflect the exit price that a market participant would be willing to receive to assume the liabilities or that a market participant would be willing to pay for the assets. As of December 31, 2025, the non-performance reserve was a $16 million gain recorded primarily to total operating revenues in the consolidated statements of operations. It is possible that future market prices could vary from those used in recording assets and liabilities and such variations could be material.

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) monitoring of counterparties’ credit limits on as needed basis; (iii) as applicable, 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.

Counterparty credit exposure includes credit risk exposure under certain long-term agreements, including solar and other PPAs. As external sources or observable market quotes are not available to estimate such exposure, the Company estimates the exposure related to 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. A significant portion of these energy-related commodity contracts are with utilities with strong credit quality and public utility commission or other regulatory support. However, such regulated utility counterparties can be impacted by changes in government regulations or adverse financial conditions, which the Company is unable to predict. Certain subsidiaries of the Company sell the output of their facilities to PG&E, a significant counterparty of the Company, under long-term PPAs, and PG&E’s credit rating is below investment-grade.

- 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

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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-Paragraph 2
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-URI https://asc.fasb.org/1943274/2147478119/940-820-50-1

+ Details

Accounting for Derivative Instruments and Hedging Activities - Schedule of Notional Amounts of Outstanding (Details) $ in Millions	12 Months Ended
	Dec. 31, 2025 USD ($) MWh BTU	Dec. 31, 2024 USD ($) MWh BTU
Long \| Interest
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount \| $	$ 4,080	$ 1,769
Heat Rate Call Option Commodity Contracts \| Short \| Power
Derivative Instruments, Gain (Loss) [Line Items]
Notional amount, energy measure \| MWh	29	25
Heat Rate Call Option Commodity Contracts \| Short \| Natural Gas
Derivative Instruments, Gain (Loss) [Line Items]
Notional amount, energy measure \| BTU	5	11

- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

+ References

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+ Details

Leases

12 Months Ended

Dec. 31, 2025

Leases [Abstract]

Leases

Accounting for Leases

The Company evaluates each arrangement at inception to determine if it contains a lease. Substantially all of the Company’s leases are operating leases.

Lessee

The Company records its operating lease liabilities at the present value of the lease payments over the lease term at lease commencement date. Lease payments include fixed payment amounts as well as variable rate payments based on an index initially measured at lease commencement date. Variable payments, including payments based on future performance and based on index changes, are recorded when the expense is probable. The Company determines the relevant lease term by evaluating whether renewal and termination options are reasonably certain to be exercised. The Company uses its incremental borrowing rate to calculate the present value of the lease payments, based on information available at the lease commencement date.

The Company’s leases consist of land leases for numerous operating asset locations, real estate leases and equipment leases. The terms and conditions for these leases vary by the type of underlying asset. Certain of these leases have both lease and non-lease components and the Company has elected to apply the practical expedient to not separate these components.

Lease expense was comprised of the following:


	Year Ended December 31,
(In millions)	2025		2024		2023
Operating lease cost - Fixed	$	51	$	31	$	40

Operating lease cost - Variable	15		12		11
Total lease cost	$	66	$	43	$	51

Operating lease information was as follows:


	Year Ended December 31,
(In millions)	2025		2024		2023
Cash paid for operating leases	$	50	$	34	$	30


(In millions, except term and rate)	December 31, 2025			December 31, 2024
Right-of-use assets - operating leases, net (a)	$	714		$	547

Short-term lease liability - operating leases (b)	$	20		$	10
Long-term lease liability - operating leases (a)	796			569
Total lease liabilities	$	816		$	579

Weighted average remaining lease term (in years)	25			26
Weighted average discount rate	5.7		%	4.5		%

(a) Increases in right-of-use assets and long-term lease liabilities are primarily due to third-party acquisitions, as further described in Note 3, Acquisitions and Dispositions.

(b) Short-term lease liability balances are included within the accrued expenses and other current liabilities line item of the consolidated balance sheets as of December 31, 2025 and 2024.

Minimum future rental payments of operating lease liabilities as of December 31, 2025 are as follows:


	(In millions)
2026	$	63
2027	63
2028	64
2029	62
2030	63
Thereafter	1,214
Total lease payments	1,529
Less imputed interest	(713)
Total lease liability - operating leases	$	816

The Company is party to various land lease agreements with wholly-owned subsidiaries of CEG that are accounted for as operating leases. The following table summarizes the land lease agreements:


(In millions)	Right-of-use assets, net		Long-term lease liabilities		Lease expiration
As of December 31, 2025
Daggett 2	$	22	$	23	June 30, 2058
Daggett 3	29		34		December 18, 2062
Luna Valley	16		19		September 23, 2058
Mililani I	18		21		March 31, 2057
Oahu Solar (a)	17		19		August 1, 2057
Rosamond Central (a)	10		12		March 31, 2056
Rosamond South I	14		16		September 30, 2058

As of December 31, 2024
Daggett 2	$	22	$	23	June 30, 2058
Daggett 3	30		34		December 18, 2062
Mililani I	18		21		March 31, 2057
Oahu Solar (a)	17		19		August 1, 2057
Rosamond Central (a)	11		12		March 31, 2056

(a) The Company has the ability to extend each of these leases for two additional five-year periods.

Lessor

The majority of the Company’s revenue is obtained through PPAs or other contractual agreements that are accounted for as leases. These leases are comprised of both fixed payments and variable payments contingent upon volumes or performance metrics. Many of the leases have renewal options at the end of the lease term. Termination may be allowed under specific circumstances in the lease arrangements, such as under an event of default. All but one of the Company’s active leases are operating leases. This sales-type lease is further described below. Certain of these operating leases have both lease and non-lease components, and the Company allocates the transaction price to the components based on standalone selling prices.

The following amounts of energy, capacity and other revenues are related to the Company’s operating leases:


	Flexible Generation		Renewables & Storage		Total
December 31, 2025	(In millions)
Energy revenue	$	2	$	783	$	785
Capacity revenue	113		63		176

Operating revenues	$	115	$	846	$	961


	Flexible Generation		Renewables & Storage		Total
December 31, 2024	(In millions)
Energy revenue	$	3	$	817	$	820
Capacity revenue	110		43		153

Operating revenues	$	113	$	860	$	973


	Flexible Generation		Renewables & Storage		Total
December 31, 2023	(In millions)
Energy revenue	$	4	$	760	$	764
Capacity revenue	249		20		269
Other revenues (a)	21		—		21
Operating revenues	$	274	$	780	$	1,054

(a) On May 31, 2023, the Marsh Landing Black Start addition reached commercial operations and the Company receives an annual fixed fee over a five-year term under the related agreement. The agreement was determined to be a sales-type lease resulting in the Company recording a lease receivable of $21 million included in total operating revenues, offset by net investment costs of $13 million included in cost of operations, resulting in a net pre-tax profit of $8 million. The lease receivable is included in other current and non-current assets on the Company’s consolidated balance sheet.

Minimum future rent payments the Company expects to receive for the remaining periods related to various facility operating leases as of December 31, 2025 were as follows:


	(In millions)
2026	$	214
2027	215
2028	213
2029	211
2030	212
Thereafter	1,918
Total lease payments	$	2,983

Property, plant and equipment, net related to the Company’s operating leases were as follows:


(In millions)	December 31, 2025		December 31, 2024
Property, plant and equipment	$	6,642	$	6,284
Accumulated depreciation	(2,520)		(2,276)
Net property, plant and equipment	$	4,122	$	4,008

Leases

Accounting for Leases

The Company evaluates each arrangement at inception to determine if it contains a lease. Substantially all of the Company’s leases are operating leases.

Lessee

Lease expense was comprised of the following:


	Year Ended December 31,
(In millions)	2025		2024		2023
Operating lease cost - Fixed	$	51	$	31	$	40

Operating lease cost - Variable	15		12		11
Total lease cost	$	66	$	43	$	51

Operating lease information was as follows:


	Year Ended December 31,
(In millions)	2025		2024		2023
Cash paid for operating leases	$	50	$	34	$	30


(In millions, except term and rate)	December 31, 2025			December 31, 2024
Right-of-use assets - operating leases, net (a)	$	714		$	547

Short-term lease liability - operating leases (b)	$	20		$	10
Long-term lease liability - operating leases (a)	796			569
Total lease liabilities	$	816		$	579

Weighted average remaining lease term (in years)	25			26
Weighted average discount rate	5.7		%	4.5		%

(a) Increases in right-of-use assets and long-term lease liabilities are primarily due to third-party acquisitions, as further described in Note 3, Acquisitions and Dispositions.

(b) Short-term lease liability balances are included within the accrued expenses and other current liabilities line item of the consolidated balance sheets as of December 31, 2025 and 2024.

Minimum future rental payments of operating lease liabilities as of December 31, 2025 are as follows:


	(In millions)
2026	$	63
2027	63
2028	64
2029	62
2030	63
Thereafter	1,214
Total lease payments	1,529
Less imputed interest	(713)
Total lease liability - operating leases	$	816

The Company is party to various land lease agreements with wholly-owned subsidiaries of CEG that are accounted for as operating leases. The following table summarizes the land lease agreements:


(In millions)	Right-of-use assets, net		Long-term lease liabilities		Lease expiration
As of December 31, 2025
Daggett 2	$	22	$	23	June 30, 2058
Daggett 3	29		34		December 18, 2062
Luna Valley	16		19		September 23, 2058
Mililani I	18		21		March 31, 2057
Oahu Solar (a)	17		19		August 1, 2057
Rosamond Central (a)	10		12		March 31, 2056
Rosamond South I	14		16		September 30, 2058

As of December 31, 2024
Daggett 2	$	22	$	23	June 30, 2058
Daggett 3	30		34		December 18, 2062
Mililani I	18		21		March 31, 2057
Oahu Solar (a)	17		19		August 1, 2057
Rosamond Central (a)	11		12		March 31, 2056

(a) The Company has the ability to extend each of these leases for two additional five-year periods.

Lessor

The following amounts of energy, capacity and other revenues are related to the Company’s operating leases:


	Flexible Generation		Renewables & Storage		Total
December 31, 2025	(In millions)
Energy revenue	$	2	$	783	$	785
Capacity revenue	113		63		176

Operating revenues	$	115	$	846	$	961


	Flexible Generation		Renewables & Storage		Total
December 31, 2024	(In millions)
Energy revenue	$	3	$	817	$	820
Capacity revenue	110		43		153

Operating revenues	$	113	$	860	$	973


	Flexible Generation		Renewables & Storage		Total
December 31, 2023	(In millions)
Energy revenue	$	4	$	760	$	764
Capacity revenue	249		20		269
Other revenues (a)	21		—		21
Operating revenues	$	274	$	780	$	1,054

Minimum future rent payments the Company expects to receive for the remaining periods related to various facility operating leases as of December 31, 2025 were as follows:


	(In millions)
2026	$	214
2027	215
2028	213
2029	211
2030	212
Thereafter	1,918
Total lease payments	$	2,983

Property, plant and equipment, net related to the Company’s operating leases were as follows:


(In millions)	December 31, 2025		December 31, 2024
Property, plant and equipment	$	6,642	$	6,284
Accumulated depreciation	(2,520)		(2,276)
Net property, plant and equipment	$	4,122	$	4,008

Accounting for Derivative Instruments and Hedging Activities - Schedule of Derivative Instruments, Gain (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized gain (loss) on derivatives, net of tax	$ (44)	$ (33)
Interest rate contracts
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized gain (loss) on derivatives, net of tax	(31)	29	$ (17)
Long-term Power Commodity Contracts
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized gain (loss) on derivatives, net of tax	(20)	(32)	23
Heat Rate Call Option Commodity Contracts
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized gain (loss) on derivatives, net of tax	$ 1	$ (2)	$ 2

- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

+ References

+ Details

- Definition

The net change in the difference between the fair value and the carrying value, or in the comparative fair values, of derivative instruments, including options, swaps, futures, and forward contracts, held at each balance sheet date, that was included in earnings for the period.

+ References + Details

Leases (Tables)

12 Months Ended

Dec. 31, 2025

Leases [Abstract]

Schedule of Lease Information and Expense

Lease expense was comprised of the following:


	Year Ended December 31,
(In millions)	2025		2024		2023
Operating lease cost - Fixed	$	51	$	31	$	40

Operating lease cost - Variable	15		12		11
Total lease cost	$	66	$	43	$	51

Operating lease information was as follows:


	Year Ended December 31,
(In millions)	2025		2024		2023
Cash paid for operating leases	$	50	$	34	$	30


(In millions, except term and rate)	December 31, 2025			December 31, 2024
Right-of-use assets - operating leases, net (a)	$	714		$	547

Short-term lease liability - operating leases (b)	$	20		$	10
Long-term lease liability - operating leases (a)	796			569
Total lease liabilities	$	816		$	579

Weighted average remaining lease term (in years)	25			26
Weighted average discount rate	5.7		%	4.5		%

(a) Increases in right-of-use assets and long-term lease liabilities are primarily due to third-party acquisitions, as further described in Note 3, Acquisitions and Dispositions.

(b) Short-term lease liability balances are included within the accrued expenses and other current liabilities line item of the consolidated balance sheets as of December 31, 2025 and 2024.

Schedule of Maturities of Operating Lease Liabilities

Minimum future rental payments of operating lease liabilities as of December 31, 2025 are as follows:


	(In millions)
2026	$	63
2027	63
2028	64
2029	62
2030	63
Thereafter	1,214
Total lease payments	1,529
Less imputed interest	(713)
Total lease liability - operating leases	$	816

Schedule of Land Lease with Wholly-Owned Subsidiary

The Company is party to various land lease agreements with wholly-owned subsidiaries of CEG that are accounted for as operating leases. The following table summarizes the land lease agreements:


(In millions)	Right-of-use assets, net		Long-term lease liabilities		Lease expiration
As of December 31, 2025
Daggett 2	$	22	$	23	June 30, 2058
Daggett 3	29		34		December 18, 2062
Luna Valley	16		19		September 23, 2058
Mililani I	18		21		March 31, 2057
Oahu Solar (a)	17		19		August 1, 2057
Rosamond Central (a)	10		12		March 31, 2056
Rosamond South I	14		16		September 30, 2058

As of December 31, 2024
Daggett 2	$	22	$	23	June 30, 2058
Daggett 3	30		34		December 18, 2062
Mililani I	18		21		March 31, 2057
Oahu Solar (a)	17		19		August 1, 2057
Rosamond Central (a)	11		12		March 31, 2056

(a) The Company has the ability to extend each of these leases for two additional five-year periods.

Schedule of Energy and Capacity Revenue

The following amounts of energy, capacity and other revenues are related to the Company’s operating leases:


	Flexible Generation		Renewables & Storage		Total
December 31, 2025	(In millions)
Energy revenue	$	2	$	783	$	785
Capacity revenue	113		63		176

Operating revenues	$	115	$	846	$	961


	Flexible Generation		Renewables & Storage		Total
December 31, 2024	(In millions)
Energy revenue	$	3	$	817	$	820
Capacity revenue	110		43		153

Operating revenues	$	113	$	860	$	973


	Flexible Generation		Renewables & Storage		Total
December 31, 2023	(In millions)
Energy revenue	$	4	$	760	$	764
Capacity revenue	249		20		269
Other revenues (a)	21		—		21
Operating revenues	$	274	$	780	$	1,054

Schedule of Minimum Future Rent Payments Under the Operating Leases

Minimum future rent payments the Company expects to receive for the remaining periods related to various facility operating leases as of December 31, 2025 were as follows:


	(In millions)
2026	$	214
2027	215
2028	213
2029	211
2030	212
Thereafter	1,918
Total lease payments	$	2,983

Schedule of Property, Plant, and Equipment Net

Property, plant and equipment, net related to the Company’s operating leases were as follows:


(In millions)	December 31, 2025		December 31, 2024
Property, plant and equipment	$	6,642	$	6,284
Accumulated depreciation	(2,520)		(2,276)
Net property, plant and equipment	$	4,122	$	4,008

Summary of Significant Accounting Policies - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Disaggregation of Revenue [Line Items]
Operating revenues	$ 1,429	$ 1,371	$ 1,314
Total operating revenues	1,429	1,371	1,314
Less: Lease revenue	(797)	(831)	(780)
Flexible Generation \| Energy Revenue
Disaggregation of Revenue [Line Items]
Less: Lease revenue	(2)	(3)	(4)
Flexible Generation \| Capacity Revenue
Disaggregation of Revenue [Line Items]
Less: Lease revenue	(113)	(110)	(249)
Renewables & Storage \| Energy Revenue
Disaggregation of Revenue [Line Items]
Less: Lease revenue	(783)	(817)	(760)
Renewables & Storage \| Capacity Revenue
Disaggregation of Revenue [Line Items]
Less: Lease revenue	(63)	(43)	(20)
Operating Segments
Disaggregation of Revenue [Line Items]
Operating revenues	1,429	1,371	1,314
Contract amortization	(189)	(184)	(186)
Mark-to-market for economic hedges	(23)	(35)	19
Total operating revenues	1,429	1,371	1,314
Less: Contract amortization	189	184	186
Less: Mark-to-market for economic hedges	23	35	(19)
Less: Lease revenue	$ (961)	$ (973)	$ (1,054)
Operating Lease, Lease Income, Statement of Income or Comprehensive Income [Extensible Enumeration]	Total operating revenues	Total operating revenues	Total operating revenues
Total revenue from contracts with customers	$ 680	$ 617	$ 427
Operating Segments \| Energy Revenue
Disaggregation of Revenue [Line Items]
Operating revenues	1,196	1,173	1,023
Total operating revenues	1,196	1,173	1,023
Operating Segments \| Capacity Revenue
Disaggregation of Revenue [Line Items]
Operating revenues	369	327	359
Total operating revenues	369	327	359
Operating Segments \| Other Revenues
Disaggregation of Revenue [Line Items]
Operating revenues	76	90	99
Total operating revenues	76	90	99
Operating Segments \| Flexible Generation
Disaggregation of Revenue [Line Items]
Operating revenues	291	342	420
Contract amortization	(18)	(18)	(20)
Mark-to-market for economic hedges	6	9	(5)
Total operating revenues	291	342	420
Less: Contract amortization	18	18	20
Less: Mark-to-market for economic hedges	(6)	(9)	5
Less: Lease revenue	(115)	(113)	(274)
Total revenue from contracts with customers	188	238	171
Operating Segments \| Flexible Generation \| Energy Revenue
Disaggregation of Revenue [Line Items]
Operating revenues	30	84	81
Total operating revenues	30	84	81
Operating Segments \| Flexible Generation \| Capacity Revenue
Disaggregation of Revenue [Line Items]
Operating revenues	269	262	336
Total operating revenues	269	262	336
Operating Segments \| Flexible Generation \| Other Revenues
Disaggregation of Revenue [Line Items]
Operating revenues	4	5	28
Total operating revenues	4	5	28
Operating Segments \| Renewables & Storage
Disaggregation of Revenue [Line Items]
Operating revenues	1,138	1,029	894
Contract amortization	(171)	(166)	(166)
Mark-to-market for economic hedges	(29)	(44)	24
Total operating revenues	1,138	1,029	894
Less: Contract amortization	171	166	166
Less: Mark-to-market for economic hedges	29	44	(24)
Less: Lease revenue	(846)	(860)	(780)
Total revenue from contracts with customers	492	379	256
Operating Segments \| Renewables & Storage \| Energy Revenue
Disaggregation of Revenue [Line Items]
Operating revenues	1,166	1,089	942
Total operating revenues	1,166	1,089	942
Operating Segments \| Renewables & Storage \| Capacity Revenue
Disaggregation of Revenue [Line Items]
Operating revenues	100	65	23
Total operating revenues	100	65	23
Operating Segments \| Renewables & Storage \| Other Revenues
Disaggregation of Revenue [Line Items]
Operating revenues	72	85	71
Total operating revenues	$ 72	$ 85	$ 71

Property, Plant, and Equipment - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Property, Plant and Equipment [Line Items]
Depreciation expense	$ 662	$ 610	$ 514
Mt Storm And Goat Wind Facilities
Property, Plant and Equipment [Line Items]
Depreciation expense	$ 22

Property, Plant and Equipment

12 Months Ended

Dec. 31, 2025

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

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


	December 31, 2025		December 31, 2024		Depreciable Lives
	(In millions)
Facilities and equipment	$	15,095	$	13,302	3 - 40 Years
Land and improvements	644		537
Construction in progress (a) (b)	530		191
Total property, plant and equipment	16,269		14,030
Accumulated depreciation	(4,673)		(4,086)
Net property, plant and equipment	$	11,596	$	9,944

(a) As of December 31, 2025 and 2024, construction in progress included $24 million and $23 million, respectively, of capital expenditures that relate to prepaid long-term service agreements for facilities in the Flexible Generation segment.

(b) As of December 31, 2025 and 2024, construction in progress included $12 million and $9 million, respectively, of accrued non-cash capital expenditures.

Depreciation expense related to property, plant and equipment during the years ended December 31, 2025, 2024 and 2023 was $662 million, $610 million and $514 million, respectively. The Company accelerated depreciation of both the Mt. Storm and Goat Mountain wind facilities related to the repowering of the facilities, which resulted in additional depreciation expense in the amount of $22 million for the year ended December 31, 2025.

The Company recorded long-lived asset impairments during the year ended December 31, 2023, as further described in Note 9, Asset Impairments.

Accounting for Derivative Instruments and Hedging Activities (Tables)

12 Months Ended

Dec. 31, 2025

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Notional Amounts of Outstanding

The following table summarizes the net notional volume buy/(sell) of the Company’s open derivative transactions broken out by commodity:


		Total Volume
		December 31, 2025		December 31, 2024
Commodity	Units	(In millions)
Power	MWh	(29)		(25)
Natural Gas	MMBtu	5		11
Interest	Dollars	$	4,080	$	1,769

Schedule of Fair Value of Derivative Instruments

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


	Fair Value
	Derivative Assets				Derivative Liabilities
	December 31, 2025		December 31, 2024		December 31, 2025		December 31, 2024
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current	$	2	$	5	$	6	$	—
Interest rate contracts long-term	29		22		21		—
Total Derivatives Designated as Cash Flow Hedges	$	31	$	27	$	27	$	—
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current	$	17	$	30	$	—	$	—
Interest rate contracts long-term	94		109		—		—
Energy-related commodity contracts current	10		4		46		56
Energy-related commodity contracts long-term	4		5		287		315
Total Derivatives Not Designated as Cash Flow Hedges	$	125	$	148	$	333	$	371
Total Derivatives	$	156	$	175	$	360	$	371

Schedule of Offsetting of Derivatives

The following tables summarize the offsetting of derivatives by counterparty:



	Gross Amounts Not Offset in the Statement of Financial Position
As of December 31, 2025	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Net Amount
Energy-related commodity contracts	(In millions)
Derivative assets	$	14	$	—	$	14
Derivative liabilities	(333)		—		(333)
Total energy-related commodity contracts	$	(319)	$	—	$	(319)
Interest rate contracts
Derivative assets	$	142	$	—	$	142
Derivative liabilities	(27)		—		(27)
Total interest rate contracts	$	115	$	—	$	115
Total derivative instruments	$	(204)	$	—	$	(204)


	Gross Amounts Not Offset in the Statement of Financial Position
As of December 31, 2024	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Net Amount
Energy-related commodity contracts	(In millions)
Derivative assets	$	9	$	—	$	9
Derivative liabilities	(371)		—		(371)
Total energy-related commodity contracts	$	(362)	$	—	$	(362)
Interest rate contracts
Derivative assets	$	166	$	—	$	166

Total interest rate contracts	$	166	$	—	$	166
Total derivative instruments	$	(196)	$	—	$	(196)

Schedule of Cash Flow Hedge Included in OCI (OCL)

The following table summarizes the effects on the Company’s accumulated OCI (OCL) balance attributable to interest rate swaps designated as cash flow hedge derivatives:


	Year ended December 31,
	2025		2024		2023
	(In millions)
Accumulated OCI beginning balance	$	15	$	20	$	27

Rosamond South I Drop Down (a)	(4)		—		—
Daggett 1 Drop Down	(6)		—		—
Luna Valley Drop Down	(8)		—		—
Pine Forest Drop Down	5		—		—
Honeycomb Portfolio Drop Down	(3)		—		—
Reclassified from accumulated OCI to income due to realization of previously deferred amounts	(3)		(1)		(5)
Mark-to-market of cash flow hedge accounting contracts	(2)		(4)		(2)
Accumulated (OCL) OCI ending balance	$	(6)	$	15	$	20
Accumulated OCI attributable to noncontrolling interests	4		8		5
Accumulated (OCL) OCI attributable to Clearway Energy LLC	$	(10)	$	7	$	15
Losses expected to be realized from OCL during the next 12 months	$	(6)

(a) Represents $2 million attributable to the Company and $2 million attributable to noncontrolling interests.

Schedule of Derivative Instruments, Gain (Loss)

Mark-to-market gains/(losses) related to the Company’s derivatives are recorded in the consolidated statements of operations as follows:


	Year ended December 31,
	2025		2024		2023
	(In millions)
Interest Rate Contracts (Interest expense)	$	(31)	$	29	$	(17)
Energy-Related Commodity Contracts (Mark-to-market for economic hedging activities included in Total operating revenues) (a)	(20)		(32)		23
Energy-Related Commodity Contracts (Mark-to-market for economic hedging activities included in Cost of operations) (b)	1		(2)		2

(a) Relates to long-term energy-related commodity contracts at Elbow Creek, Mesquite Star, Mt. Storm, Langford and Mesquite Sky and heat rate call option energy-related commodity contracts at El Segundo, Marsh Landing and Walnut Creek.

(b) Relates to backbone transportation service energy-related commodity contracts at El Segundo and Walnut Creek.

Nature of Business (Details)	12 Months Ended
Nature of Business (Details)	Dec. 31, 2025 state segment GW
Nature of Business
Power generation capacity, gigawatts (over)	12.9
Number of states \| state	27
Number of reportable segments \| segment	2
Number of operating segments \| segment	2
Clearway Energy LLC \| GIP
Nature of Business
Voting interest (as a percentage)	54.90%
Clearway Energy LLC \| Shareholders
Nature of Business
Voting interest (as a percentage)	45.10%
Clearway Energy LLC \| Clearway Energy, Inc.
Nature of Business
Ownership interest (as a percentage)	58.62%
CEG \| Clearway Energy LLC
Nature of Business
Ownership interest (as a percentage)	41.38%
Conventional Generation, Utility-Scale Solar, Distributed Solar, and Wind
Nature of Business
Power generation capacity, gigawatts (over)	10.1
Generational Facilities and District Energy Systems
Nature of Business
Power generation capacity, gigawatts (over)	2.8

Fair Value of Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2025

Fair Value Disclosures [Abstract]

Schedule of Estimated Carrying Values and Fair Values

The carrying amounts and estimated fair values of the Company’s recorded financial instruments not carried at fair market value or that do not approximate fair value are as follows:


	As of December 31, 2025				As of December 31, 2024
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(In millions)


Liabilities:
Long-term debt, including current portion — affiliate	$	6	$	6	$	—	$	—
Long-term debt, including current portion — external (a)	8,676		8,382		7,237		6,715

(a) Excludes net debt issuance costs, which are recorded as a reduction to long-term debt on the Company’s consolidated balance sheets.

Schedule of Fair Value Option, Disclosures

The following table presents the level within the fair value hierarchy for long-term debt, including current portion:


	As of December 31, 2025				As of December 31, 2024
	Level 2		Level 3		Level 2		Level 3
	(In millions)
Long-term debt, including current portion	$	2,038	$	6,350	$	1,922	$	4,793

Schedule of Fair Value, Assets and Liabilities

The following table presents 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, 2025				As of December 31, 2024
	Fair Value (a)				Fair Value (a)
(In millions)	Level 2 (b)		Level 3		Level 2 (b)		Level 3
Derivative assets
Energy-related commodity contracts (c)	$	1	$	13	$	—	$	9
Interest rate contracts	142		—		166		—
Other financial instruments (d)	—		7		—		10
Total assets	$	143	$	20	$	166	$	19
Derivative liabilities
Energy-related commodity contracts (e)	$	—	$	333	$	—	$	371
Interest rate contracts	27		—		—		—
Total liabilities	$	27	$	333	$	—	$	371

(a) There were no derivative assets or liabilities classified as Level 1 as of December 31, 2025 and 2024.

(c) Includes short-term backbone transportation service contracts classified as Level 2 and heat rate call option contracts classified as Level 3.

(d) Includes SREC contract.

The following table reconciles the beginning and ending balances for instruments that are recognized at fair value in the consolidated financial statements using significant unobservable inputs:


	Year ended December 31,
		2025		2024
(In millions)	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
Beginning balance		$	(352)	$	(317)
Settlements		83		(2)


Total losses for the period included in earnings		(44)		(33)
Ending balance		$	(313)	$	(352)
Change in unrealized losses included in earnings for derivatives and other financial instruments held as of December 31,		$	(44)	$	(33)

Schedule of Fair Value Measurement Inputs and Valuation Techniques

The following tables quantify the significant unobservable inputs used in developing the fair value of the Company’s Level 3 positions:


	December 31, 2025
	Fair Value						Input/Range
	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
	(In millions)
Long-term Power Commodity Contracts	$	—	$	330	Discounted Cash Flow	Forward Market Price ($ per MWh)	$	34.04	$	89.73	$	56.51
Heat Rate Call Option Commodity Contracts	13		3		Option Model	Forward Market Price ($ per MWh)	$	(29.26)	$	260.77	$	42.23
					Option Model	Forward Market Price ($ per MMBtu)	$	0.92	$	10.15	$	3.02
Other Financial Instruments	7		—		Discounted Cash Flow	Forecast annual generation levels of certain DG solar facilities	60,047 MWh		120,094 MWh		108,791 MWh


	December 31, 2024
	Fair Value						Input/Range
	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
	(In millions)
Long-term Power Commodity Contracts	$	—	$	366	Discounted Cash Flow	Forward Market Price ($ per MWh)	$	21.60	$	80.82	$	45.44
Heat Rate Call Option Commodity Contracts	9		5		Option Model	Forward Market Price ($ per MWh)	$	(19.30)	$	1,011.79	$	45.87
					Option Model	Forward Market Price $ (per MMBtu)	$	0.85	$	10.55	$	3.25
Other Financial Instruments	10		—		Discounted Cash Flow	Forecast annual generation levels of certain DG solar facilities	59,425 MWh		118,850 MWh		111,091 MWh

The following table provides the impact on the fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2025 and 2024:

Type

Significant Observable Input

Position

Change In Input

Impact on Fair Value Measurement

Energy-Related Commodity Contracts

Forward Market Price Power

Sell

Increase/(Decrease)

Lower/(Higher)

Energy-Related Commodity Contracts

Forward Market Price Gas

Sell

Increase/(Decrease)

Higher/(Lower)

Other Financial Instruments

Forecast Generation Levels

Sell

Increase/(Decrease)

Higher/(Lower)

Segment Reporting (Details) - USD ($) $ in Millions		3 Months Ended			6 Months Ended	9 Months Ended	12 Months Ended
Segment Reporting (Details) - USD ($) $ in Millions	May 31, 2023	Sep. 30, 2025	Jun. 30, 2025	Mar. 31, 2025	Jun. 30, 2025	Sep. 30, 2025	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Segment Reporting
Operating revenues							$ 1,429	$ 1,371	$ 1,314
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below							528	501	473
Depreciation, amortization and accretion							682	627	526
Impairment losses							0	0	12
General and administrative							40	38	35
Transaction and integration costs							16	8	4
Operating Income							163	197	264
Equity in earnings of unconsolidated affiliates							31	35	12
Other income, net							29	48	52
Loss on debt extinguishment							(8)	(5)	(6)
Interest expense							(387)	(307)	(337)
Loss Before Income Taxes							(172)	(32)	(15)
Income tax (benefit) expense							(1)	1	(2)
Net Loss	$ 8						(171)	(33)	(13)
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests		$ (316)	$ (45)	$ (99)	$ (144)	$ (460)	(555)	(236)	(162)
Net Income Attributable to Clearway Energy LLC		$ 345	$ 64	$ (5)	$ 59	$ 404	384	203	149
Equity investments in affiliates							291	309
Capital expenditures							196	188
Total assets							16,444	14,320
Operating Segments
Segment Reporting
Operating revenues							1,429	1,371	1,314
Corporate
Segment Reporting
Operating revenues							0	0	0
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below							0	(3)	(2)
Depreciation, amortization and accretion							0	0	0
Impairment losses									0
General and administrative							40	38	35
Transaction and integration costs							16	8	4
Operating Income							(56)	(43)	(37)
Equity in earnings of unconsolidated affiliates							0	0	0
Other income, net							3	11	24
Loss on debt extinguishment							0	0	0
Interest expense							(100)	(96)	(97)
Loss Before Income Taxes							(153)	(128)	(110)
Income tax (benefit) expense							0	0	0
Net Loss							(153)	(128)	(110)
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests							0	0	0
Net Income Attributable to Clearway Energy LLC							(153)	(128)	(110)
Equity investments in affiliates							0	0
Capital expenditures							0	0
Total assets							84	151
Flexible Generation \| Operating Segments
Segment Reporting
Operating revenues							291	342	420
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below							109	137	154
Depreciation, amortization and accretion							112	115	129
Impairment losses									0
General and administrative							0	0	0
Transaction and integration costs							0	0	0
Operating Income							70	90	137
Equity in earnings of unconsolidated affiliates							1	3	3
Other income, net							4	6	4
Loss on debt extinguishment							0	0	0
Interest expense							(35)	(35)	(35)
Loss Before Income Taxes							40	64	109
Income tax (benefit) expense							0	0	0
Net Loss							40	64	109
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests							0	0	0
Net Income Attributable to Clearway Energy LLC							40	64	109
Equity investments in affiliates							72	75
Capital expenditures							9	9
Total assets							1,803	1,933
Renewables & Storage \| Operating Segments
Segment Reporting
Operating revenues							1,138	1,029	894
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below							419	367	321
Depreciation, amortization and accretion							570	512	397
Impairment losses									12
General and administrative							0	0	0
Transaction and integration costs							0	0	0
Operating Income							149	150	164
Equity in earnings of unconsolidated affiliates							30	32	9
Other income, net							22	31	24
Loss on debt extinguishment							(8)	(5)	(6)
Interest expense							(252)	(176)	(205)
Loss Before Income Taxes							(59)	32	(14)
Income tax (benefit) expense							(1)	1	(2)
Net Loss							(58)	31	(12)
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests							(555)	(236)	(162)
Net Income Attributable to Clearway Energy LLC							497	267	$ 150
Equity investments in affiliates							219	234
Capital expenditures							187	179
Total assets							$ 14,557	$ 12,236
SCE \| Flexible Generation
Segment Reporting
Customer's percentage of total revenue							7.00%	7.00%	11.00%
SCE \| Renewables & Storage
Segment Reporting
Customer's percentage of total revenue							15.00%	17.00%	13.00%
PG&E \| Flexible Generation
Segment Reporting
Customer's percentage of total revenue							2.00%	3.00%	4.00%
PG&E \| Renewables & Storage
Segment Reporting
Customer's percentage of total revenue							14.00%	14.00%	13.00%
CALIFORNIA \| Geographic Concentration Risk \| Revenue Benchmark
Segment Reporting
Concentration risk percentage							58.00%
CALIFORNIA \| Geographic Concentration Risk \| Assets
Segment Reporting
Concentration risk percentage							45.00%

Investments Accounted for by the Equity Method and Variable Interest Entities - Schedule of Financial Information of Equity Method Investments (Details) - USD ($) $ in Millions		12 Months Ended
	May 31, 2023	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Schedule of Equity Method Investments [Line Items]
Operating revenues		$ 1,429	$ 1,371	$ 1,314
Operating income		163	197	264
Net income	$ 8	(171)	(33)	(13)
Current assets		1,148	1,058
Current liabilities		1,023	722
Non-current liabilities		9,393	7,957
Desert Sunlight
Schedule of Equity Method Investments [Line Items]
Operating revenues		205	206	202
Operating income		149	146	144
Net income		118	113	108
Current assets		77	81
Non-current assets		1,025	1,086
Current liabilities		66	63
Non-current liabilities		653	726
Other
Schedule of Equity Method Investments [Line Items]
Operating revenues		96	95	94
Operating income		31	25	23
Net income		22	16	$ 13
Current assets		72	63
Non-current assets		358	391
Current liabilities		33	27
Non-current liabilities		$ 208	$ 225

CONSOLIDATED STATEMENTS OF MEMBERS' EQUITY - USD ($) $ in Millions	Total	CEG	Tax Equity Investors	Clearway Energy, Inc.	Contributed Capital	Contributed Capital CEG	Contributed Capital Clearway Energy, Inc.	Retained Earnings	Retained Earnings CEG	Retained Earnings Clearway Energy, Inc.	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interest	Noncontrolling Interest Tax Equity Investors	Noncontrolling Interest Clearway Energy, Inc.
Balance, beginning of period at Dec. 31, 2022	$ 4,160				$ 1,308			$ 1,240			$ 21	$ 1,591
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(30)							149				(179)
Unrealized (loss) gain on derivatives and changes in accumulated OCI	(7)										(6)	(1)
Distributions/(Contributions) to/from CEG, net of distributions, cash		$ (78)				$ (78)
Contributions from noncontrolling interests, net of distributions, cash			$ 1,123										$ 1,123
Distributions to noncontrolling interests, non-cash	(7)											(7)
Contributions from Clearway, Inc., non-cash				$ 13			$ 13
Tax-related distributions	(51)							(51)
Transfer of assets under common control	286				12							274
Buyout of noncontrolling interest	(10)				27							(37)
Buyout of redeemable noncontrolling interest	17				17
Distributions paid		(131)		(180)					$ (131)	$ (180)
Balance, end of period at Dec. 31, 2023	5,105				1,299			1,027			15	2,764
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(46)							203				(249)
Unrealized (loss) gain on derivatives and changes in accumulated OCI	(5)										(8)	3
Distributions/(Contributions) to/from CEG, net of distributions, cash		194				194
Contributions from noncontrolling interests, net of distributions, cash			1,321										1,321
Distributions to noncontrolling interests, non-cash	(1)											(1)
Tax-related distributions	(2)							(2)
Transfer of assets under common control	(593)				(586)							(7)
Buyout of noncontrolling interest	(7)				(4)							(3)
Buyout of redeemable noncontrolling interest	7				7
Distributions paid		(140)		(194)					(140)	(194)
Other	2				1							1
Balance, end of period at Dec. 31, 2024	5,641				911			894			7	3,829
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	49							384				(335)
Unrealized (loss) gain on derivatives and changes in accumulated OCI	(5)										(3)	(2)
Distributions/(Contributions) to/from CEG, net of distributions, cash		112		49		$ 112	$ (3)							$ 46
Contributions from noncontrolling interests, net of distributions, cash			$ 708										$ 708
Distributions to noncontrolling interests, non-cash	(4)											(4)
Pro-rata distributions to CEG, cash		(19)		(25)					(19)	(25)
Transfer of assets under common control	(267)				(433)						(14)	180
Buyout of noncontrolling interest	(3)											(3)
Proceeds from the issuance of Class C units	48				48
Distributions paid		$ (149)		$ (209)					$ (149)	$ (209)
Other	(1)							1
Balance, end of period at Dec. 31, 2025	$ 5,925				$ 641			$ 875			$ (10)	$ 4,419

Acquisitions and Dispositions (Tables)

12 Months Ended

Dec. 31, 2025

Business Combination, Asset Acquisition, Transaction between Entities under Common Control, and Joint Venture Formation [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed

The following is a summary of assets and liabilities transferred in connection with the acquisition as of June 10, 2025:


(In millions)	Pine Forest
Restricted cash	$	1
Property, plant and equipment (a)	560
Right-of-use assets, net	17
Derivative assets	6

Total assets acquired	584

Long-term debt (b)	515
Long-term lease liabilities	18
Derivative liabilities	1
Other current and non-current liabilities	54
Total liabilities assumed	588
Other comprehensive income	5
Net liabilities assumed	$	(9)

(a) Includes Construction in progress of $550 million.

(b) Includes a $103 million construction loan, a $102 million cash equity bridge loan, a $41 million tax equity bridge loan and a $275 million tax credit transfer bridge loan, offset by $6 million in unamortized debt issuance costs. See Note 10, Long-term Debt, for further discussion of the long-term debt assumed in the acquisition.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of October 15, 2025:


(In millions)	Honeycomb Portfolio
Cash	$	1
Property, plant and equipment (a)	480
Right-of-use assets, net	3
Derivative assets	4
Other current and non-current assets	7

Total assets acquired	495

Long-term debt (b)	443
Long-term lease liabilities	3
Derivative liabilities	7
Other current and non-current liabilities	47
Total liabilities assumed	500
Other comprehensive loss	(3)
Net liabilities assumed	$	(2)

(a) Includes Construction in progress of $473 million.

(b) Includes a $218 million construction loan and a $234 million tax equity bridge loan, offset by $9 million in unamortized debt issuance costs. See Note 10, Long-term Debt, for further discussion of the long-term debt assumed in the acquisition.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of April 29, 2025:


(In millions)	Daggett 1
Cash	$	1
Property, plant and equipment (a)	223

Other current and non-current assets	8

Total assets acquired	232

Long-term debt (b)	220

Derivative liabilities	6
Other current and non-current liabilities	11
Total liabilities assumed	237
Other comprehensive loss	(6)
Net assets acquired	$	1

(a) Includes Construction in progress of $221 million.

(b) Includes a $92 million construction loan and a $131 million tax equity bridge loan, offset by $3 million in unamortized debt issuance costs. See Note 10, Long-term Debt, for further discussion of the long-term debt assumed in the acquisition.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of April 29, 2025:


(In millions)	Luna Valley
Restricted cash	$	8
Property, plant and equipment (a)	346
Right-of-use assets, net (b)	16
Other current and non-current assets	22

Total assets acquired	392

Long-term debt (c)	348
Long-term lease liabilities (b)	18
Derivative liabilities	8
Other current and non-current liabilities	33
Total liabilities assumed	407
Other comprehensive loss	(8)
Net liabilities assumed	$	(7)

(a) Includes Construction in progress of $338 million.

(b) Balances primarily relate to a land lease agreement with a wholly-owned subsidiary of CEG, which expires on September 23, 2058.

(c) Includes a $144 million construction loan, a $64 million cash equity bridge loan and a $144 million tax equity bridge loan, offset by $4 million in unamortized debt issuance costs. See Note 10, Long-term Debt, for further discussion of the long-term debt assumed in the acquisition.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of March 20, 2025:


(In millions)	Rosamond South I

Property, plant and equipment (a)	$	507
Right-of-use assets, net (b)	17

Other current and non-current assets	11

Total assets acquired	535

Long-term debt (c)	468
Long-term lease liabilities (b)	19
Derivative liabilities	4
Other current and non-current liabilities	51
Total liabilities assumed	542
Other comprehensive loss	(4)
Net liabilities assumed	$	(3)

(a) Includes Construction in progress of $495 million.

(b) Balances primarily relate to a land lease agreement with a wholly-owned subsidiary of CEG, which expires on September 30, 2058.

(c) Includes a $179 million construction loan, a $6 million cash equity bridge loan and a $284 million tax equity bridge loan, offset by $1 million in unamortized debt issuance costs. See Note 10, Long-term Debt, for further discussion of the long-term debt assumed in the acquisition.

The acquisition was determined to be an asset acquisition and the purchase price, including transaction expenses, was allocated to the fair value of the assets acquired and liabilities assumed on the acquisition date as follows:


(In millions)	Catalina
Cash	$	15
Intangible asset for power purchase agreement	175
Right-of-use assets	107
Other current and non-current assets	6

Total assets acquired	303

Long-term lease liabilities	173
Other current and non-current liabilities	2
Total liabilities assumed	175
Net assets acquired	$	128

The following is a summary of assets and liabilities transferred in connection with the acquisition as of November 18, 2024:


(In millions)	Dan’s Mountain

Property, plant and equipment (a)	$	152
Right-of-use assets	3



Total assets acquired	155

Long-term debt (b)	125
Long-term lease liabilities	3
Other current and non-current liabilities	29
Total liabilities assumed	157
Net liabilities assumed	$	(2)

(a) Includes Construction in progress of $150 million.

(b) Includes a $77 million cash equity bridge loan and a $49 million tax equity bridge loan, offset by $1 million in unamortized debt issuance costs. See Note 10, Long-term Debt, for further discussion of the long-term debt assumed in the acquisition.


(In millions)	Tuolumne
Property, plant and equipment	$	37
Intangible asset for power purchase agreement	176
Right-of-use assets	5
Other current and non-current assets	1

Total assets acquired	219

Long-term lease liabilities	4
Other current and non-current liabilities	4
Total liabilities assumed	8
Net assets acquired	$	211

The following is a summary of assets and liabilities transferred in connection with the acquisition as of December 1, 2023:


(In millions)	Rosamond Central BESS
Property, plant and equipment (a)	$	275

Total assets acquired	275

Other current and non-current liabilities	9
Total liabilities assumed	9
Net assets acquired	$	266

(a) Includes Construction in progress of $272 million.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of October 31, 2023:


(In millions)	Victory Pass and Arica
Cash	$	1
Property, plant and equipment (a)	937
Right-of-use assets, net	4
Derivative assets	1
Other non-current assets	6

Total assets acquired	949

Long-term debt (b)	864
Long-term lease liabilities	4
Other current and non-current liabilities	82
Total liabilities assumed	950
Net liabilities assumed	$	(1)

(a) Includes Construction in progress of $893 million.

(b) Includes a $483 million cash equity bridge loan and $385 million tax equity bridge loan, offset by $4 million in unamortized debt issuance costs. See Note 10, Long-term Debt, for further discussion of the long-term debt assumed in the acquisition.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of April 16, 2024:


(In millions)	Cedar Creek
Restricted cash	$	1
Property, plant and equipment	311
Right-of-use assets, net	6
Derivative assets	14
Other current and non-current assets	14

Total assets acquired	346

Long-term debt (a)	309
Long-term lease liabilities	7
Other current and non-current liabilities	13
Total liabilities assumed	329
Net assets acquired	$	17

(a) Includes a $112 million construction loan, a $91 million cash equity bridge loan, and a $109 million tax equity bridge loan, offset by $3 million in unamortized debt issuance costs. See Note 10, Long-term Debt, for further discussion of the long-term debt assumed in the acquisition.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of March 15, 2024:


(In millions)	Texas Solar Nova 2
Restricted cash	$	1
Property, plant and equipment	280
Right-of-use assets, net	21
Derivative assets	6
Other current and non-current assets	4

Total assets acquired	312

Long-term debt (a)	194
Long-term lease liabilities	19
Other current and non-current liabilities	27
Total liabilities assumed	240
Net assets acquired	$	72

(a) Includes an $80 million term loan and a $115 million tax equity bridge loan, offset by $1 million in unamortized debt issuance costs. See Note 10, Long-term Debt, for further discussion of the long-term debt assumed in the acquisition.

Schedule of Assets and Liabilities Transferred with Disposition

The following is a summary of assets and liabilities transferred in connection with the disposition as of October 2, 2025:


(In millions)	Mt. Storm
Property, plant and equipment	$	54


Other current and non-current assets	6

Total assets transferred	60


Other current and non-current liabilities	9
Total liabilities transferred	9
Net assets transferred	$	51

- Definition

Tabular disclosure of information related to a disposal group. Includes, but is not limited to, a discontinued operation, disposal classified as held-for-sale or disposed of by means other than sale or disposal of an individually significant component.

+ References

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-Name Accounting Standards Codification
-Section 50
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Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef
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-Name Accounting Standards Codification
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-Paragraph 3A
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Reference 3: http://www.xbrl.org/2009/role/commonPracticeRef
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-Name Accounting Standards Codification
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Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
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-Name Accounting Standards Codification
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Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
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-Name Accounting Standards Codification
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Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
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+ Details

Intangible Assets (Tables)

12 Months Ended

Dec. 31, 2025

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of the Components of the Company's intangible Assets Subject to Amortization

The following tables summarize the components of intangible assets subject to amortization:


Year ended December 31, 2025	PPAs		Leasehold Rights		Emission Allowances		Other		Total
(In millions)
January 1, 2025	$	3,265	$	86	$	17	$	19	$	3,387
Acquisitions (a)	351		—		—		—		351
Other	—		—		—		4		4

December 31, 2025	3,616		86		17		23		3,742
Less accumulated amortization	(1,322)		(46)		(6)		(8)		(1,382)
Net carrying amount	$	2,294	$	40	$	11	$	15	$	2,360

(a) The weighted average life of acquired intangibles was 14 years for PPAs.


Year ended December 31, 2024	PPAs		Leasehold Rights		Emission Allowances		Other		Total
(In millions)
January 1, 2024	$	3,265	$	86	$	17	$	15	$	3,383

Other	—		—		—		4		4
December 31, 2024	3,265		86		17		19		3,387
Less accumulated amortization	(1,140)		(42)		(5)		(7)		(1,194)
Net carrying amount	$	2,125	$	44	$	12	$	12	$	2,193

Leases - Schedule of Maturities of Operating Lease Liabilities (Details) $ in Millions	Dec. 31, 2025 USD ($)
Leases [Abstract]
2026	$ 63
2027	63
2028	64
2029	62
2030	63
Thereafter	1,214
Total lease payments	1,529
Less imputed interest	(713)
Total lease liability - operating leases	$ 816

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Current Assets
Cash and cash equivalents	$ 231	$ 332
Restricted cash	587	401
Inventory	75	64
Derivative instruments	29	39
Prepayments and other current assets	63	58
Total current assets	1,148	1,058
Property, plant and equipment, net	11,596	9,944
Other Assets
Equity investments in affiliates	291	309
Intangible assets for power purchase agreements, net	2,294	2,125
Other intangible assets, net	66	68
Derivative instruments	127	136
Right-of-use assets, net	714	547
Other non-current assets	208	133
Total other assets	3,700	3,318
Total Assets	16,444	14,320
Current Liabilities
Current portion of long-term debt — external	708	430
Current portion of long-term debt — affiliate	6	0
Accounts payable — trade	95	82
Derivative instruments	52	56
Accrued interest expense	52	53
Accrued expenses and other current liabilities	78	66
Total current liabilities	1,023	722
Other Liabilities
Long-term debt — external	7,898	6,750
Deferred income taxes	2	3
Derivative instruments	308	315
Long-term lease liabilities	796	569
Other non-current liabilities	389	320
Total other liabilities	9,393	7,957
Total Liabilities	10,416	8,679
Redeemable noncontrolling interest in subsidiaries	103	0
Commitments and Contingencies
Members’ Equity
Contributed capital	641	911
Retained earnings	875	894
Accumulated other comprehensive (loss) income	(10)	7
Noncontrolling interest	4,419	3,829
Total Members’ Equity	5,925	5,641
Total Liabilities and Members’ Equity	16,444	14,320
Nonrelated Party
Current Assets
Accounts receivable	162	164
Affiliated Entity
Current Assets
Accounts receivable	1	0
Current Liabilities
Accounts payable — affiliates	$ 32	$ 35

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2025

Accounting Policies [Abstract]

Schedule of Cash and Cash Equivalents

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


	December 31,
	2025		2024
	(In millions)
Cash and cash equivalents	$	231	$	332
Restricted cash	587		401
Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows	$	818	$	733

Schedule of Restricted Cash


	December 31,
	2025		2024
	(In millions)
Cash and cash equivalents	$	231	$	332
Restricted cash	587		401
Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows	$	818	$	733

Schedule of Supplemental Cash Flow Information

The following table provides a disaggregation of the amounts classified as Acquisition of Drop Down Assets, net of cash acquired, shown in the consolidated statements of cash flows:


	Year ended December 31,
	2025		2024		2023
	(In millions)
Cash paid to acquire Drop Down Assets	$	(329)	$	(680)	$	(173)
Cash acquired from the acquisition of Drop Down Assets	11		2		128
Acquisition of Drop Down Assets, net of cash acquired	$	(318)	$	(678)	$	(45)

Schedule of Disaggregation of Revenue

The following tables represent the Company’s disaggregation of revenue from contracts with customers, along with the reportable segment for each category:


	Year ended December 31, 2025
(In millions)	Flexible Generation		Renewables & Storage		Total
Energy revenue (a)	$	30	$	1,166	$	1,196
Capacity revenue (a)	269		100		369
Other revenues	4		72		76
Contract amortization	(18)		(171)		(189)
Mark-to-market for economic hedges	6		(29)		(23)
Total operating revenues	291		1,138		1,429
Less: Contract amortization	18		171		189
Less: Mark-to-market for economic hedges	(6)		29		23
Less: Lease revenue	(115)		(846)		(961)

Total revenue from contracts with customers	$	188	$	492	$	680

(a) See Note 15, Leases, for the amounts of energy and capacity revenues that relate to leases and are accounted for under ASC 842.


	Year ended December 31, 2024
(In millions)	Flexible Generation		Renewables & Storage		Total
Energy revenue (a)	$	84	$	1,089	$	1,173
Capacity revenue (a)	262		65		327
Other revenues (a)	5		85		90
Contract amortization	(18)		(166)		(184)
Mark-to-market for economic hedges	9		(44)		(35)
Total operating revenues	342		1,029		1,371
Less: Contract amortization	18		166		184
Less: Mark-to-market for economic hedges	(9)		44		35
Less: Lease revenue	(113)		(860)		(973)
Total revenue from contracts with customers	$	238	$	379	$	617

(a) See Note 15, Leases, for the amounts of energy, capacity and other revenues that relate to leases and are accounted for under ASC 842.


	Year ended December 31, 2023
(In millions)	Flexible Generation		Renewables & Storage		Total
Energy revenue (a)	$	81	$	942	$	1,023
Capacity revenue (a)	336		23		359
Other revenues	28		71		99
Contract amortization	(20)		(166)		(186)
Mark-to-market for economic hedges	(5)		24		19
Total operating revenues	420		894		1,314
Less: Contract amortization	20		166		186
Less: Mark-to-market for economic hedges	5		(24)		(19)
Less: Lease revenue	(274)		(780)		(1,054)
Total revenue from contracts with customers	$	171	$	256	$	427

(a) See Note 15, Leases, for the amounts of energy and capacity revenues that relate to leases and are accounted for under ASC 842.

Schedule of Contract with Customer, Asset and Liability

The following table reflects the contract assets included on the Company’s consolidated balance sheets:


(In millions)	December 31, 2025		December 31, 2024
Accounts receivable, net - Contracts with customers	$	76	$	75
Accounts receivable, net - Leases	86		89
Total accounts receivable, net	$	162	$	164

Schedule of Change in Asset Retirement Obligation

The following table represents the balance of AROs, along with the related activity:


(In millions)
Balance as of December 31, 2023	$	239
Revisions in estimated cash flows	(1)
Liabilities incurred	14
Liabilities settled	(2)
Accretion expense	16
Balance as of December 31, 2024	266
Revisions in estimated cash flows	7
Liabilities incurred	38
Liabilities settled	(5)
Accretion expense	18
Balance as of December 31, 2025	$	324

Schedule of Redeemable Noncontrolling Interest


	(In millions)
Balance at December 31, 2023	$	1
Cash distributions to redeemable noncontrolling interests	(2)
Comprehensive income attributable to redeemable noncontrolling interests	13
Repurchase of redeemable noncontrolling interest	(12)
Balance at December 31, 2024	—
Cash contributions to redeemable noncontrolling interests, net of distributions	335
Non-cash distributions to redeemable noncontrolling interests	(12)
Comprehensive loss attributable to redeemable noncontrolling interests	(220)
Balance at December 31, 2025	$	103

Leases - Schedule of Energy and Capacity Revenue (Details) - USD ($) $ in Millions		12 Months Ended
	May 31, 2023	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Disaggregation of Revenue [Line Items]
Lease revenue		$ 797	$ 831	$ 780
Renewal period	5 years
Lease receivable	$ 21
Net investment costs	13
Net loss	$ 8	(171)	(33)	(13)
Total Segments \| Energy Revenue
Disaggregation of Revenue [Line Items]
Lease revenue		785	820	764
Total Segments \| Capacity Revenue
Disaggregation of Revenue [Line Items]
Lease revenue		176	153	269
Total Segments \| Other Revenue
Disaggregation of Revenue [Line Items]
Lease revenue				21
Total Segments \| Operating revenue
Disaggregation of Revenue [Line Items]
Lease revenue		961	973	1,054
Flexible Generation \| Energy Revenue
Disaggregation of Revenue [Line Items]
Lease revenue		2	3	4
Flexible Generation \| Capacity Revenue
Disaggregation of Revenue [Line Items]
Lease revenue		113	110	249
Flexible Generation \| Other Revenue
Disaggregation of Revenue [Line Items]
Lease revenue				21
Flexible Generation \| Operating revenue
Disaggregation of Revenue [Line Items]
Lease revenue		115	113	274
Renewables & Storage \| Energy Revenue
Disaggregation of Revenue [Line Items]
Lease revenue		783	817	760
Renewables & Storage \| Capacity Revenue
Disaggregation of Revenue [Line Items]
Lease revenue		63	43	20
Renewables & Storage \| Other Revenue
Disaggregation of Revenue [Line Items]
Lease revenue				0
Renewables & Storage \| Operating revenue
Disaggregation of Revenue [Line Items]
Lease revenue		$ 846	$ 860	$ 780

Long-term Debt

12 Months Ended

Dec. 31, 2025

Debt Disclosure [Abstract]

Long-term Debt

The Company’s borrowings, including short-term and long-term portions, consisted of the following:


	Maturity Date	December 31, 2025		December 31, 2024		Interest rate % (a)
		(In millions, except rates)
Intercompany Note with Clearway, Inc.	2026	$	6	$	—	3.61	%
Senior Notes	2028-2032	2,125		2,125		3.750% - 4.750%
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility (b) (c)	2028	361		—		S+1.750%
Non-recourse facility-level debt:
Fixed rate	2031-2040	3,001		3,190		2.339% - 8.000%
Variable rate	2026-2033	3,187		1,920		S+1.375% - 2.750%
Total debt		8,680		7,235
Less current maturities		(714)		(430)
Less net debt issuance costs		(70)		(57)
Add premiums (d)		2		2
Total long-term debt		$	7,898	$	6,750

(a) As of December 31, 2025, S+ equals SOFR plus x%.

(b) Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement, and only applies to outstanding borrowings.

(c) During January 2026, the Company repaid all of the outstanding borrowings under the revolving credit facility utilizing the proceeds from the sale of the 2034 Senior Notes, as further described below.

(d) Premiums relate to the 2028 Senior Notes.

The financing arrangements listed above contain certain covenants, including financial covenants that the Company is required to be in compliance with during the term of each respective arrangement. Under the facility-level financing arrangements, each facility is permitted to pay distributions out of available cash as long as certain conditions are satisfied, including that no default under the applicable arrangements has occurred and that each facility is otherwise in compliance with all relevant conditions under the financing agreements, including meeting required financial ratios, where applicable. The Company’s facility-level financing arrangements are non-recourse to the Company, thus, each facility pledges its underlying assets as collateral, and if a facility is in default under its financing arrangement, then the related lender could demand repayment of the facility’s obligations or enforce its security interests with respect to the pledged collateral.

As of December 31, 2025, the Company had $1,063 million in letters of credit outstanding, $96 million of which is related to the Company’s revolving credit facility. Also as of December 31, 2025, the Company was in compliance with all of the required covenants.

2034 Senior Notes

On January 13, 2026, Clearway Energy Operating LLC completed the sale of $600 million aggregate principal amount of senior unsecured notes due 2034, or the 2034 Senior Notes. The 2034 Senior Notes bear interest at 5.750% and mature on January 15, 2034. Interest on the 2034 Senior Notes is payable semi-annually on January 15 and July 15 of each year, beginning on July 15, 2026. The 2034 Senior Notes are unsecured obligations of Clearway Energy Operating LLC and are guaranteed by Clearway Energy LLC and by certain of Clearway Energy Operating LLC’s wholly-owned current and future subsidiaries. The net proceeds from the 2034 Senior Notes were used to repay $361 million in outstanding borrowings under the revolving credit facility and for general corporate purposes.

Facility-level Debt

Deriva Solar Portfolio

On February 5, 2026, in order to partially fund the third-party acquisition of the Deriva Solar Portfolio, which is expected to close in the first half of 2026, the Company, through its indirect subsidiary, Cardinal Investment Holdco LLC, entered into a financing agreement that provides for a term loan of up to $100 million and $119 million in letters of credit in support of debt service and facility obligations. The financing will be supported by the Company’s interest in the Deriva Solar Portfolio upon closing of the acquisition. Upon funding, the term loan will bear interest a rate of SOFR plus 2.00% per annum and will mature 364 days after the funding date.

Pine Forest

On June 10, 2025, as part of the acquisition of Pine Forest, as further described in Note 3, Acquisitions and Dispositions, the Company assumed the facility’s financing agreement, which included a $103 million construction loan, a $102 million cash equity bridge loan, a $41 million tax equity bridge loan and a $275 million tax credit transfer bridge loan, offset by $6 million in unamortized debt issuance costs. A partial payment of $54 million was made on the cash equity bridge loan at acquisition date utilizing all of the proceeds from the Company, which were contributed back to the Company by CEG, and the third-party cash equity investor related to the Pine Forest TargetCo acquisition.

On December 17, 2025, when Pine Forest reached substantial completion, the Company paid $50 million to Clearway Renew as an additional purchase price, as further described in Note 3, Acquisitions and Dispositions, the third-party cash equity investor contributed $144 million, Clearway, Inc., through its indirect subsidiary, Pine Forest TE Class A, contributed an additional $38 million for its Class A membership interests in Pine Forest TE HoldCo LLC and CEG contributed $49 million, which were utilized, along with the $9 million previously held in escrow, to repay the $100 million cash equity bridge loan, to repay the $41 million tax equity bridge loan, to partially repay $44 million of the tax credit transfer bridge loan, to fund $39 million in construction completion reserves, which is included in restricted cash on the Company’s consolidated balance sheet, and to pay $15 million in associated fees. Additionally, on December 17, 2025, the outstanding construction loans were converted to a term loan in the amount of $103 million that matures on December 17, 2030. Subsequent to the acquisition during 2025, the Company borrowed an additional $52 million in cash equity bridge loans.

In January 2026, the Company repaid the $231 million outstanding on the tax credit transfer bridge loan utilizing the proceeds received from the sale of transferable ITCs, and distributed the remaining $51 million to CEG.

Honeycomb Portfolio

On October 15, 2025, as part of the acquisition of the Honeycomb Portfolio, as further described in Note 3, Acquisitions and Dispositions, the Company assumed the facility’s financing agreement, which included a $218 million construction loan that converts to a term loan at substantial completion, which is expected to occur in the first half of 2026, and a $234 million tax equity bridge loan, offset by $9 million in unamortized debt issuance costs. The tax equity bridge loan will be repaid at substantial completion with the final proceeds received from the tax equity investor, as well as the Company’s additional purchase price, along with the $59 million that was contributed into escrow by the tax equity investor at acquisition date, which is included in restricted cash on the Company’s consolidated balance sheet. Subsequent to the acquisition during 2025, the Company borrowed an additional $38 million in construction loans through December 31, 2025.

Daggett 1

On April 29, 2025, as part of the acquisition of Daggett 1, as further described in Note 3, Acquisitions and Dispositions, the Company assumed the facility’s financing agreement, which included a $92 million construction loan and a $131 million tax equity bridge loan, offset by $3 million in unamortized debt issuance costs.

On September 19, 2025, when Daggett 1 reached substantial completion, the Company paid $42 million to Clearway Renew as additional purchase price, as further described in Note 3, Acquisitions and Dispositions, and the tax equity investor contributed an additional $108 million, which was utilized, along with the $38 million previously held in escrow and $31 million in construction loan proceeds, to repay the $131 million tax equity bridge loan, to fund $6 million in construction completion reserves, which is included in restricted cash on the Company’s consolidated balance sheet, and to pay $7 million in associated fees with the remaining $33 million distributed to CEG. Additionally, on September 19, 2025, the outstanding construction loans were converted to a term loan in the amount of $132 million that matures on September 19, 2030. Subsequent to the acquisition during 2025, the Company borrowed an additional $40 million in construction loans.

Luna Valley

On April 29, 2025, as part of the acquisition of Luna Valley, as further described in Note 3, Acquisitions and Dispositions, the Company assumed the facility’s financing agreement, which included a $144 million construction loan, a $64 million cash equity bridge loan and a $144 million tax equity bridge loan, offset by $4 million in unamortized debt issuance costs. A partial payment of $18 million was made on the cash equity bridge loan at acquisition date utilizing all of the proceeds from the Company, which were contributed back to the Company by CEG.

On September 4, 2025, when Luna Valley facility reached substantial completion, the Company paid $72 million to Clearway Renew as additional purchase price, as further described in Note 3, Acquisitions and Dispositions, the tax equity investor contributed an additional $114 million and CEG contributed $50 million, which were utilized, along with the $29 million previously held in escrow and $28 million in construction loan proceeds, to repay the $46 million cash equity bridge loan, to repay the $144 million tax equity bridge loan, to fund $22 million in construction completion reserves, which is included in restricted cash on the Company’s consolidated balance sheet, and to pay $9 million in associated fees. Additionally, on September 4, 2025, the outstanding construction loans were converted to a term loan in the amount of $195 million that matures on September 4, 2030. Subsequent to the acquisition during 2025, the Company borrowed an additional $51 million in construction loans.

Rosamond South I

On March 20, 2025, as part of the acquisition of Rosamond South I, as further described in Note 3, Acquisitions and Dispositions, the Company assumed the facility’s financing agreement, which included a $179 million construction loan, a $6 million cash equity bridge loan and a $284 million tax equity bridge loan, offset by $1 million in unamortized debt issuance costs. The cash equity bridge loan was repaid at acquisition date, along with $3 million in associated fees, utilizing $2 million from the third-party cash equity investor, as well as all of the proceeds from the Company, which were contributed back to the Company by CEG, and an additional $3 million contributed by CEG.

On August 13, 2025, when Rosamond South I reached substantial completion, the Company paid $29 million to Clearway Renew as additional purchase price, as further described in Note 3, Acquisitions and Dispositions, the third-party cash equity investor contributed an additional $41 million and the tax equity investor contributed an additional $226 million, which were utilized, along with the $58 million previously held in escrow and $13 million in construction loan proceeds, to repay the $276 million tax equity bridge loan and to pay $9 million in associated fees with the remaining $53 million distributed to CEG. Additionally, on August 13, 2025, the outstanding construction loans were converted to a term loan in the amount of $228 million that matures on August 13, 2030. Subsequent to the acquisition during 2025, the Company borrowed an additional $49 million in construction loans and also received $46 million in contributions from CEG to pay for construction completion expenses.

Dan’s Mountain

On November 18, 2024, as part of the acquisition of Dan’s Mountain, as further described in Note 3, Acquisitions and Dispositions, the Company assumed the facility’s financing agreement, which included a $77 million cash equity bridge loan and a $49 million tax equity bridge loan, offset by $1 million in unamortized debt issuance costs. A partial payment of $7 million was made on the cash equity bridge loan at acquisition date utilizing all of the proceeds from the Company, which were contributed back to the Company by CEG.

On May 21, 2025, when the Dan’s Mountain facility reached substantial completion, the Company paid $36 million to Clearway Renew as additional purchase price, as further described in Note 3, Acquisitions and Dispositions. Also on May 21, 2025, a third-party cash equity investor contributed $45 million to acquire the Class B membership interests in Dan’s Mountain TargetCo from Clearway Renew and the tax equity investor contributed an additional $90 million. The Company utilized the combined proceeds from the third-party cash equity and tax equity investors, along with the Company’s entire additional purchase price, which was contributed back to the Company by CEG, and the $18 million previously held in escrow, to repay the $91 million tax equity bridge loan, to repay the $70 million cash equity bridge loan and to pay $2 million in associated fees with the remaining $26 million distributed to CEG. Subsequent to the acquisition, the Company borrowed an additional $24 million in tax equity bridge loans during 2024 and $18 million in tax equity bridge loans during 2025. The Company also received $16 million in contributions from CEG to pay for construction completion expenses during 2025.

Tuolumne

On April 29, 2025, in order to partially fund the third-party acquisition of the Tuolumne wind facility, as further described in Note 3, Acquisitions and Dispositions, the Company entered into a financing agreement, which included the issuance of a $163 million term loan, as well as $22 million in letters of credit in support of debt service and facility obligations, supported by the Company’s interests in the Tuolumne wind facility. The term loan bears interest at a rate of SOFR plus 1.625% per annum and matures on April 29, 2030.

Buckthorn Solar

On April 9, 2025, the Company, through its indirect subsidiary, Buckthorn Solar Portfolio LLC, refinanced its existing credit agreement, which was scheduled to mature in May 2025, resulting in the issuance of a $104 million term loan facility, as well as $22 million in letters of credit in support of debt service and facility obligations, supported by the Company’s interests in the Buckthorn Solar facility. The term loan bears interest at a rate of SOFR plus 1.625% per annum and matures on April 9, 2031. The Company utilized the proceeds from the term loan and existing sources of liquidity to pay off the existing debt in the amount of $112 million.

Cedro Hill Repowering

On December 12, 2023, the Company entered into a financing agreement for non-recourse debt for a total commitment of $254 million, which consists of construction loans, a tax equity bridge loan and a cash equity bridge loan, related to the repowering of the Cedro Hill wind facility. The Company’s initial borrowing of $165 million was utilized to repay the $72 million of outstanding principal under the original financing agreement, to pay $55 million to Clearway Renew for the future delivery of equipment, which was included in other non-current assets on the Company’s consolidated balance sheet, to pay $27 million to a third party for the future delivery of equipment, which was included in other non-current assets on the Company’s consolidated balance sheet, to pay a $4 million development services fee to Clearway Renew, to pay for $4 million in debt issuance costs that were deferred and to pay for $3 million in capital expenditures. During 2024, the $82 million of equipment was delivered, and therefore, was included in property, plant and equipment, net on the Company’s consolidated balance sheet as of December 31, 2024.

On December 27, 2024, when the repowering of the Cedro Hill wind facility reached substantial completion, tax equity investors contributed $152 million to acquire the Class A membership interests in Cedro Hill TE Holdco LLC, a tax equity fund that owns the Cedro Hill wind facility. The tax equity proceeds were utilized, along with $54 million in construction loan proceeds, to repay the $138 million tax equity bridge loan, the $16 million cash equity bridge loan, to fund $38 million in construction completion and related reserves, which was included in restricted cash on the Company’s consolidated balance sheet, to pay $11 million in construction invoices and to pay $4 million in associated fees with the remaining $26 million distributed to CEG. Also at substantial completion, the outstanding construction loans were converted to a term loan in the amount of $99 million. Under the new financing agreement, the Company borrowed $88 million during 2024.

Capistrano Portfolio Holdco LLC

On October 23, 2024, the Company, through its indirect subsidiary, Capistrano Portfolio Holdco LLC, entered into a financing agreement, which included the issuance of a $121 million term loan, as well as $42 million in letters of credit in support of debt service and facility obligations, supported by the Company’s interests in the Broken Bow, Crofton Bluffs, Mountain Wind 1 and Mountain Wind 2 wind facilities. The Company utilized the proceeds from the term loan to pay off the existing debt in the amount of $63 million related to Broken Bow and Crofton Bluffs and to pay related financing costs.

Natural Gas Holdco LC Facility

On July 25, 2024, the Company, through its indirect subsidiary, Natural Gas Holdco, entered into a financing agreement that provides for a $200 million letter of credit facility, which is being utilized to support the collateral needs of the merchant facilities in the Flexible Generation segment. The letter of credit facility has an initial term of three years and the option for two additional one-year extensions.

Rosamond Central (Rosie Class B LLC)

On June 30, 2023, Rosie Class B LLC, the indirect owner of the Rosamond Central solar facility, amended its financing agreement to provide for (i) a refinanced term loan in the amount of $77 million, (ii) construction loans up to $115 million, (iii) tax equity bridge loans up to $188 million, (iv) an increase to the letter of credit sublimit to $41 million and (v) an extension of the maturity date of the term loan and construction loans to June 13, 2029.

On July 3, 2023, Rosie Class B LLC issued a loan to Clearway Renew, utilizing a portion of the loan proceeds under the amended financing agreement, in order to finance the construction of the BESS facility. On December 1, 2023, the Rosamond Central solar facility acquired the BESS facility from Clearway Renew for initial cash consideration of $70 million, as further described in Note 3, Acquisitions and Dispositions, and Clearway Renew utilized the funds to partially repay the loan.

On June 13, 2024, when the Rosamond Central BESS facility reached substantial completion, Clearway Renew repaid the $184 million outstanding loan balance owed to Rosie Class B LLC utilizing the additional purchase price of $279 million paid by the Company, as further described in Note 3, Acquisitions and Dispositions. The Company utilized the proceeds from Clearway Renew, along with $39 million held previously in escrow and $56 million of the Company’s additional purchase price that was contributed back to the Company by CEG, to repay the $186 million tax equity bridge loan, to distribute $44 million to the third-party cash equity investor, to fund $21 million in construction completion reserves, which was included in restricted cash on the Company’s consolidated balance sheet, and to pay $11 million in associated fees. Additionally, on June 13, 2024, the outstanding construction loans were converted to a term loan in the amount of $115 million. Under the amended financing agreement, the Company borrowed $271 million during 2023 and $30 million during 2024.

NIMH Solar

On June 11, 2024, the Company, through its indirect subsidiary, NIMH Solar LLC, refinanced its amended and restated credit agreement, which was scheduled to mature in September 2024, resulting in the issuance of a $137 million term loan facility, as well as $17 million in letters of credit in support of debt service and facility obligations. The obligations under the new financing arrangement are supported by the Company’s interests in the Alpine, Blythe and Roadrunner solar facilities. The Company utilized the proceeds from the term loan and existing sources of liquidity to pay off the existing debt in the amount of $146 million.

Victory Pass and Arica

On October 31, 2023, as part of the acquisition of Victory Pass and Arica, as further described in Note 3, Acquisitions and Dispositions, the Company assumed the facility’s financing agreement, which included a $483 million cash equity bridge loan and a $385 million tax equity bridge loan, offset by $4 million in unamortized debt issuance costs. A partial payment of $133 million was made on the cash equity bridge loan at acquisition date utilizing all of the proceeds from the Company, which were contributed back to the Company by CEG, and the contribution from the third-party cash equity investor.

On May 1, 2024, when the facilities reached substantial completion, the Company paid $165 million to Clearway Renew as additional purchase price, as further described in Note 3, Acquisitions and Dispositions, the third-party cash equity investor contributed an additional $347 million, the tax equity investor contributed an additional $410 million and CEG contributed $52 million, which were utilized, along with $103 million held previously in escrow, to repay the $351 million cash equity bridge loan, to repay the $468 million tax equity bridge loan, to fund $75 million in construction completion reserves, which was included in restricted cash on the Company’s consolidated balance sheet, and to pay $18 million in associated fees. Subsequent to the acquisition, the Company borrowed an additional $22 million during 2023 and $62 million during 2024.

Cedar Creek

On April 16, 2024, as part of the acquisition of Cedar Creek, as further described in Note 3, Acquisitions and Dispositions, the Company assumed the facility’s financing agreement, which included a $112 million construction loan, a $91 million cash equity bridge loan and a $109 million tax equity bridge loan, offset by $3 million in unamortized debt issuance costs. At acquisition date, the tax equity investor contributed $108 million, which was utilized, along with the Company’s entire purchase price that was contributed back to the Company by CEG, to repay the tax equity bridge loan, to repay the cash equity bridge loan, to partially repay $2 million in construction loans, to fund $16 million in construction completion reserves, which was included in restricted cash on the Company’s consolidated balance sheet, and to pay $6 million in associated fees. Also at acquisition date, the outstanding construction loans were converted to a term loan in the amount of $110 million.

Texas Solar Nova 1 and Texas Solar Nova 2

On December 28, 2023, as part of the acquisition of Texas Solar Nova 1, the Company assumed the facility’s financing agreement, which included a $90 million construction loan, $109 million cash equity bridge loan and $151 million tax equity bridge loan, offset by $1 million in unamortized debt issuance costs. At acquisition date, the tax equity investor contributed $148 million, which was utilized, along with the Company’s entire purchase price that was contributed back to the Company by CEG and the proceeds from the third-party cash equity investor, to repay the $109 million cash equity bridge loan, to repay the $151 million tax equity bridge loan, to fund $18 million in construction completion reserves, which was included in restricted cash on the Company’s consolidated balance sheet, and to pay $5 million in associated fees with the remaining $9 million distributed back to CEG. Also at acquisition date, the $90 million construction loan was converted into a term loan in the amount of $102 million, which includes an additional borrowing of $12 million.

On March 15, 2024, as part of the acquisition of Texas Solar Nova 2, as further described in Note 3, Acquisitions and Dispositions, the Company assumed the facility’s financing agreement, which included an $80 million term loan and a $115 million tax equity bridge loan, offset by $1 million in unamortized debt issuance costs. At acquisition date, the tax equity investor contributed $130 million, which was utilized, along with $9 million of the Company’s purchase price that was contributed back to the Company by CEG, to repay the $115 million tax equity bridge loan, to fund $19 million in construction completion reserves, which was included in restricted cash on the Company’s consolidated balance sheet, and to pay $4 million in associated fees.

Additionally, on March 15, 2024, Texas Solar Nova 1’s financing agreement was amended to merge the Texas Solar Nova 1 and Texas Solar Nova 2 term loans as a combined term loan under TSN1 Class B Member LLC.

Interest Rate Swaps

The Company enters into interest rate swap agreements in order to hedge the variability of expected future cash interest payments that may arise in connection with its non-recourse facility level debt or any potential refinancing of its Senior Notes. The facility level debt swaps amortize in proportion to their respective loans and are floating for a fixed rate where the subsidiary pays its counterparty the equivalent of a fixed interest payment on a predetermined notional amount and will receive quarterly the equivalent of a floating interest payment based on the same notional amount. All interest rate swap payments by the subsidiary and its counterparty are made quarterly and the SOFR is determined in advance of each interest period.

The following table summarizes the swaps, some of which are forward starting as indicated, related to the Company’s facility level debt and the potential refinancing of its Senior Notes:


	% of Principal		Fixed Interest Rate		Floating Interest Rate	Notional Amount at December 31, 2025 (In millions)		Effective Date	Maturity Date
Avra Valley	85	%	2.20	%	SOFR	$	23	March 31, 2023	January 31, 2031
Alta Wind Asset Management	100	%	2.22	%	SOFR	8		May 22, 2013	May 15, 2031
Buckthorn Solar	100	%	2.63	%	SOFR	100		April 9, 2025	July 31, 2043
Capistrano Portfolio Holdco	100	%	Various		SOFR	106		October 24, 2024	September 30, 2033
Carlsbad Energy Holdings	100	%	Various		SOFR	46		Various	September 30, 2027
Cedar Creek	100	%	3.02	%	SOFR	106		April 30, 2024	March 31, 2049
Cedro Hill	85	%	Various		SOFR	77		Various	September 30, 2044
Clearway Energy Operating (a)	—	%	Various		SOFR	1,093		Various	Various
Daggett 1	95	%	Various		SOFR	126		Various	Various
Daggett 2	87	%	Various		SOFR	134		March 29, 2024	March 31, 2043
Daggett 3	84	%	Various		SOFR	181		September 30, 2024	September 30, 2043
Honeycomb Portfolio (a)	85	%	Various		SOFR	694		Various	Various
Kansas South	75	%	1.93	%	SOFR	9		June 28, 2013	December 31, 2030
Luna Valley	95	%	Various		SOFR	185		Various	Various
Mililani Class B	97	%	Various		SOFR	85		Various	Various
NIMH Solar	100	%	3.25	%	SOFR	111		June 11, 2024	January 31, 2033
Oahu Solar	96	%	2.47	%	SOFR	72		November 30, 2019	October 31, 2040
Pine Forest	85	%	Various		SOFR	88		November 28, 2025	March 31, 2050
Rosie Class B	93	%	Various		SOFR	172		Various	Various
Rosie South	90	%	Various		SOFR	206		Various	Various
South Trent	90	%	Various		SOFR	13		Various	June 30, 2028
TSN1 Class B	96	%	Various		SOFR	163		March 29, 2024	September 30, 2043
Viento Funding II	90	%	2.53	%	SOFR	129		Various	December 31, 2032
Tuolumne	100	%	Various		SOFR	153		April 29, 2025	March 31, 2040
Total						$	4,080

(a) As of December 31, 2025, the notional amount includes forward swaps that are not included in the percentage of outstanding principal disclosed.

Annual Maturities

Annual payments based on the maturities of the Company’s debt, for the years ending after December 31, 2025, are as follows:


	(In millions)
2026 (a)	$	1,145
2027	364
2028	2,022
2029	863
2030	995
Thereafter	3,291
Total	$	8,680

(a) At December 31, 2025, amount includes $431 million of construction-related financings recorded in long-term debt on the Company’s consolidated balance sheet that is being funded through long-term equity contributions or is converting to long-term debt.

Intangible Assets - Schedule of Components Subject to Amortization (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Finite-lived Intangible Assets [Roll Forward]
Net carrying amount beginning balance	$ 3,742	$ 3,387	$ 3,383
Acquisitions	351
Net carrying amount ending balance	3,742	3,387	3,383
Less accumulated amortization	(1,382)	(1,194)
Net carrying amount	$ 2,360	2,193
Weighted average life of acquired intangibles	14 years
Other
Finite-lived Intangible Assets [Roll Forward]
Other	$ 4	4
PPAs
Finite-lived Intangible Assets [Roll Forward]
Net carrying amount beginning balance	3,616	3,265	3,265
Acquisitions	351
Net carrying amount ending balance	3,616	3,265	3,265
Less accumulated amortization	(1,322)	(1,140)
Net carrying amount	2,294	2,125
PPAs \| Other
Finite-lived Intangible Assets [Roll Forward]
Other	0	0
Leasehold Rights
Finite-lived Intangible Assets [Roll Forward]
Net carrying amount beginning balance	86	86	86
Acquisitions	0
Net carrying amount ending balance	86	86	86
Less accumulated amortization	(46)	(42)
Net carrying amount	40	44
Leasehold Rights \| Other
Finite-lived Intangible Assets [Roll Forward]
Other	0	0
Emission Allowances
Finite-lived Intangible Assets [Roll Forward]
Net carrying amount beginning balance	17	17	17
Acquisitions	0
Net carrying amount ending balance	17	17	17
Less accumulated amortization	(6)	(5)
Net carrying amount	11	12
Emission Allowances \| Other
Finite-lived Intangible Assets [Roll Forward]
Other	0	0
Other
Finite-lived Intangible Assets [Roll Forward]
Net carrying amount beginning balance	23	19	15
Acquisitions	0
Net carrying amount ending balance	23	19	$ 15
Less accumulated amortization	(8)	(7)
Net carrying amount	15	12
Other \| Other
Finite-lived Intangible Assets [Roll Forward]
Other	$ 4	$ 4

Summary of Significant Accounting Policies - Schedule of Change in Asset Retirement Obligation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	$ 266	$ 239
Revisions in estimated cash flows	7	(1)
Liabilities incurred	38	14
Liabilities settled	(5)	(2)
Accretion expense	18	16
Ending balance	$ 324	$ 266

Summary of Significant Accounting Policies - Schedule of Contract with Customer, Asset and Liability (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Disaggregation of Revenue [Line Items]
Total accounts receivable, net	$ 162	$ 164
Accounts receivable, net - Contracts with customers
Disaggregation of Revenue [Line Items]
Total accounts receivable, net	76	75
Accounts receivable, net - Leases
Disaggregation of Revenue [Line Items]
Total accounts receivable, net	$ 86	$ 89

- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 7
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-7

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 5
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-5

Reference 3: http://www.xbrl.org/2003/role/exampleRef
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-Name Accounting Standards Codification
-Section 55
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Reference 4: http://www.xbrl.org/2003/role/exampleRef
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Reference 5: http://www.xbrl.org/2003/role/exampleRef
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-URI https://asc.fasb.org/1943274/2147479777/606-10-55-91

Reference 6: http://www.xbrl.org/2003/role/exampleRef
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-Subparagraph (d)
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Reference 9: http://www.xbrl.org/2003/role/exampleRef
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-Section 55
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-URI https://asc.fasb.org/1943274/2147479777/606-10-55-91

+ Details

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Operating Revenues
Total operating revenues	$ 1,429	$ 1,371	$ 1,314
Operating Costs and Expenses
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below	528	501	473
Depreciation, amortization and accretion	682	627	526
Impairment losses	0	0	12
General and administrative	40	38	35
Transaction and integration costs	16	8	4
Total operating costs and expenses	1,266	1,174	1,050
Operating Income	163	197	264
Other Income (Expense)
Equity in earnings of unconsolidated affiliates	31	35	12
Other income, net	29	48	52
Loss on debt extinguishment	(8)	(5)	(6)
Interest expense	(387)	(307)	(337)
Total other expense, net	(335)	(229)	(279)
Loss Before Income Taxes	(172)	(32)	(15)
Income tax (benefit) expense	(1)	1	(2)
Net Loss	(171)	(33)	(13)
Less: Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	(555)	(236)	(162)
Net Income Attributable to Clearway Energy LLC	$ 384	$ 203	$ 149

Members' Equity

12 Months Ended

Dec. 31, 2025

Members' Equity [Abstract]

Members' Equity

Members’ Equity

At-the-Market Equity Offering Program, or the ATM Program

On August 6, 2025, the Company and Clearway, Inc. entered into an equity distribution agreement with Morgan Stanley & Co. LLC, BofA Securities, Inc., Citigroup Global Markets Inc., J.P. Morgan Securities LLC and Wells Fargo Securities LLC, as sales agents. Pursuant to the terms of the agreement, Clearway, Inc. may offer and sell shares of its Class C common stock, from time to time through the sales agents, up to an aggregate sales price of $100 million through an at-the-market equity offering program, or ATM Program. During the year ended December 31, 2025, Clearway, Inc. issued 787,980 shares of Class C common stock under the ATM Program for gross proceeds of $25 million and incurred fees of less than $1 million, which were exchanged for 787,980 of the Company’s Class C units. The net proceeds from the sale of shares under the ATM Program were used for general corporate purposes. As of December 31, 2025, approximately $75 million of Clearway, Inc.’s Class C common stock remained available for issuance under the ATM Program.

Dividend Reinvestment and Direct Stock Purchase Plan, or DRIP/DSPP

On August 6, 2025, Clearway, Inc. adopted a DRIP and DSPP, under which Clearway, Inc. registered and reserved for issuance up to an aggregate of 3,300,000 shares of Class C common stock. Under the DRIP, holders of Clearway, Inc.’s Class C common stock can designate all or a portion of their cash dividends, when paid, to be reinvested in additional shares of Clearway, Inc.’s Class C common stock. The DSPP allows (i) plan participants and registered stockholders of Clearway, Inc. who are not plan participants to purchase shares of Clearway, Inc.’s Class C common stock in the minimum amount of $50 per investment up to a maximum aggregate amount of $150,000 per calendar year; (ii) new investors who do not own shares of Clearway, Inc.’s Class C common stock to purchase shares by making an initial minimum investment of $250, up to a maximum aggregate amount of $150,000 per calendar year; and (iii) plan participants, other registered stockholders and new investors to request a waiver from Clearway, Inc. to make optional cash investments in excess of the maximum aggregate amount of $150,000 per calendar year. During the year ended December 31, 2025, Clearway, Inc. issued 793,202 shares of Class C common stock under the DSPP for gross proceeds of $25 million and incurred fees of less than $1 million, which were exchanged for 793,202 of the Company’s Class C units. The net proceeds from the sale of shares under the DSPP were used for general corporate purposes. As of December 31, 2025, approximately 2,506,798 shares of Clearway, Inc.’s Class C common stock remained available for issuance under the DRIP/DSPP.

In January 2026, Clearway, Inc. issued 1,445,244 shares of Class C common stock under the DSPP for gross proceeds of $50 million and incurred fees of less than $1 million, which were exchanged for 1,445,244 of the Company’s Class C units. As of January 31, 2026, approximately 1,061,554 shares of Clearway, Inc’s Class C common stock remained available for issuance under the DRIP/DSPP.

Distributions

The following tables list the distributions paid on the Company’s Class A, Class B, Class C and Class D units during the years ended December 31, 2025, 2024 and 2023:


	Fourth Quarter 2025		Third Quarter 2025		Second Quarter 2025		First Quarter 2025
Distributions per Class A and Class B units	$	0.4528	$	0.4456	$	0.4384	$	0.4312
Distributions per Class C and Class D units	0.4528		0.4456		0.4384		0.4312


	Fourth Quarter 2024		Third Quarter 2024		Second Quarter 2024		First Quarter 2024
Distributions per Class A and Class B units	$	0.4240	$	0.4171	$	0.4102	$	0.4033
Distributions per Class C and Class D units	0.4240		0.4171		0.4102		0.4033


	Fourth Quarter 2023		Third Quarter 2023		Second Quarter 2023		First Quarter 2023
Distributions per Class A and Class B units	$	0.3964	$	0.3891	$	0.3818	$	0.3745
Distributions per Class C and Class D units	0.3964		0.3891		0.3818		0.3745

In addition to the quarterly distributions, on June 10, 2025, the Company distributed an additional $16 million, $9 million of which was distributed to Clearway, Inc. related to its contribution through Pine Forest TE Class A, an indirect subsidiary of Clearway, Inc., to acquire the Class A membership interests in Pine Forest TE HoldCo LLC, as further described in Note 3, Acquisitions and Dispositions, and $7 million of which was distributed to CEG, which represents CEG’s pro-rata share of the additional distributions. On December 17, 2025, the Company distributed an additional $28 million, $16 million of which was distributed to Clearway, Inc. related to its additional contribution through Pine Forest TE Class A to complete its acquisition of the Class A membership interests in Pine Forest TE HoldCo LLC, as further described in Note 3, Acquisitions and Dispositions, and $12 million of which was distributed to CEG, which represents CEG’s pro-rata share of the additional distributions.

On February 17, 2026, the Company declared a quarterly distribution on its Class B and Class D units of $0.4602 per unit payable on March 16, 2026 to unit holders of record as of March 2, 2026.

- Definition

The entire disclosure for equity.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 815
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 8A
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480434/815-10-50-8A

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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-Section 50
-Paragraph 13
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481112/505-10-50-13

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
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-Section 50
-Paragraph 13
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-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481112/505-10-50-13

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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-Section 50
-Paragraph 14
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481112/505-10-50-14

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147477968/946-235-50-2

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 946
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-Name Accounting Standards Codification
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-URI https://asc.fasb.org/1943274/2147477968/946-235-50-2

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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-URI https://asc.fasb.org/1943274/2147478448/946-505-50-6

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 815
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-Section 50
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-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480237/815-40-50-6

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
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-Name Accounting Standards Codification
-Section S99
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-Publisher FASB
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Reference 10: http://fasb.org/us-gaap/role/ref/legacyRef
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-URI https://asc.fasb.org/505/tableOfContent

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
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Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
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Reference 13: http://www.xbrl.org/2003/role/disclosureRef
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-Section 50
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-URI https://asc.fasb.org/1943274/2147481112/505-10-50-13

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
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-Subparagraph (a)
-Publisher FASB
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Reference 15: http://www.xbrl.org/2003/role/disclosureRef
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Reference 16: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
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-Subparagraph (b)
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Reference 17: http://www.xbrl.org/2003/role/disclosureRef
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Reference 18: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
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Reference 19: http://www.xbrl.org/2003/role/disclosureRef
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+ Details

Cybersecurity Risk Management and Strategy Disclosure	12 Months Ended
Cybersecurity Risk Management and Strategy Disclosure	Dec. 31, 2025
Cybersecurity Risk Management, Strategy, and Governance [Line Items]
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]	Risk Management and Strategy The Company recognizes the critical importance of developing, implementing and maintaining robust cybersecurity measures to safeguard information systems and protect the confidentiality, integrity and availability of data. Managing Material Risks & Integrated Overall Risk Management The Company has strategically integrated cybersecurity risk management into its broader risk management framework to promote a company-wide culture of cybersecurity risk management. The Company’s risk management team works closely with the IT department to continuously evaluate and address cybersecurity risks in alignment with business objectives and operational needs. In addition, the Company follows the National Institute of Standards and Technology (NIST) Cybersecurity Framework (CSF). Engage Third Parties on Risk Management Recognizing the complexity and evolving nature of cybersecurity threats, the Company engages with a range of external experts, including cybersecurity consultants in evaluating and testing its cybersecurity systems. The Company’s collaboration with these third parties includes regular audits; threat and vulnerability assessments; incident response plan testing; company-wide monitoring of cybersecurity risks; and consultation on security enhancements. Oversee Third-Party Risk Due to the risks associated with the engagement of third-party vendors, service providers and business partners, the Company applies processes to manage these risks. Thorough security assessments of third-party vendors with access to internal protected data or information systems occurs before engagement, as well as ongoing monitoring to ensure compliance with relevant cybersecurity standards. The monitoring includes annual assessments by CEG’s Vice President of Information Technology and its Director of Cybersecurity and assessments on an ongoing basis by the internal cybersecurity team. These services are provided to the Company pursuant to the CEG Master Services Agreement. This approach is designed to mitigate risks related to potential data breaches or other security incidents originating from third parties. Risks from Cybersecurity Threats As of February 24, 2026, the Company was not aware of any cybersecurity threats or incidents that have materially affected, or are reasonably likely to materially affect the Company, including its business strategy, results of operations or financial standing. However, there can be no assurance that the Company’s cybersecurity processes will prevent or mitigate cybersecurity incidents or threats or that the Company’s efforts will always be successful. For further discussion regarding the Company’s cybersecurity risks, see Item 1A — Risk Factors, Risks Related to the Company’s Business.
Cybersecurity Risk Management Processes Integrated [Flag]	true
Cybersecurity Risk Management Processes Integrated [Text Block]	The Company has strategically integrated cybersecurity risk management into its broader risk management framework to promote a company-wide culture of cybersecurity risk management. The Company’s risk management team works closely with the IT department to continuously evaluate and address cybersecurity risks in alignment with business objectives and operational needs. In addition, the Company follows the National Institute of Standards and Technology (NIST) Cybersecurity Framework (CSF).
Cybersecurity Risk Management Third Party Engaged [Flag]	true
Cybersecurity Risk Third Party Oversight and Identification Processes [Flag]	true
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Flag]	false
Cybersecurity Risk Board of Directors Oversight [Text Block]	Clearway, Inc.’s Board of Directors has oversight of cybersecurity risks and is well informed with respect to the nature and scope of such risks. The Board of Directors is acutely aware of the critical nature of managing risks associated with cybersecurity threats. The Board of Directors has established oversight mechanisms to ensure effective governance in managing risks associated with cybersecurity as they recognize the significance of these risks and threats to operational integrity and stakeholder confidence.
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block]	The Vice President of Information Technology and Director of Cybersecurity each play a pivotal role in informing Clearway, Inc.’s Board of Directors on cybersecurity risks. They provide briefings to the Board of Directors on a regular basis, with a minimum frequency of once per year. These briefings encompass a broad range of topics, including: •Current cybersecurity threat landscape and emerging threats; •Status of ongoing cybersecurity initiatives and strategies; •Incident reports and learnings from any meaningful cybersecurity events; and •Compliance status and efforts with regulatory requirements and industry standards.
Cybersecurity Risk Process for Informing Board Committee or Subcommittee Responsible for Oversight [Text Block]	The Vice President of Information Technology and Director of Cybersecurity regularly inform the Company’s management of all aspects related to cybersecurity risks and incidents. This ensures that the highest levels of management are kept abreast of the cybersecurity posture and potential risks facing the Company. Furthermore, significant cybersecurity matters and strategic risk management decisions are escalated to Clearway, Inc.’s Board of Directors, ensuring that the Board of Directors have insight and can provide guidance on critical cybersecurity issues.
Cybersecurity Risk Role of Management [Text Block]	Management’s Role Managing Cybersecurity Risk The Vice President of Information Technology and Director of Cybersecurity regularly inform the Company’s management of all aspects related to cybersecurity risks and incidents. This ensures that the highest levels of management are kept abreast of the cybersecurity posture and potential risks facing the Company. Furthermore, significant cybersecurity matters and strategic risk management decisions are escalated to Clearway, Inc.’s Board of Directors, ensuring that the Board of Directors have insight and can provide guidance on critical cybersecurity issues. Monitor Cybersecurity Incidents The Vice President of Information Technology and Director of Cybersecurity are kept informed about the latest developments in cybersecurity, including emerging threats and innovative risk management techniques. They implement and oversee processes for the regular monitoring of the Company’s information systems. This includes the deployment of advanced security measures and regular system audits to identify potential vulnerabilities. In the event of a cybersecurity incident, the Company is equipped with a defined and practiced incident response plan, which includes incident response retainers from respected third parties. This plan includes immediate actions to mitigate the impact of the incident, long-term strategies for remediation and the prevention of future incidents.
Cybersecurity Risk Management Positions or Committees Responsible [Flag]	true
Cybersecurity Risk Management Positions or Committees Responsible [Text Block]	Primary responsibility for assessing, monitoring and managing cybersecurity risks is overseen by the Vice President of Information Technology and Director of Cybersecurity, whose services are provided to the Company under the CEG Master Services Agreement. With over 20 years of experience in the field of cybersecurity, the current Vice President of Information Technology’s background includes in-depth knowledge and experience in developing and executing the Company’s cybersecurity strategies. They oversee the Company’s IT governance programs; test compliance with internal, industry and regulatory standards; remediate known risks; and lead the Company’s employee training program. The current Director of Cybersecurity has over 30 years of experience in information technology across a variety of industries and compliance programs. The Director of Cybersecurity has been heavily focused on cybersecurity in regulated industries for over 10 years.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block]	Primary responsibility for assessing, monitoring and managing cybersecurity risks is overseen by the Vice President of Information Technology and Director of Cybersecurity, whose services are provided to the Company under the CEG Master Services Agreement. With over 20 years of experience in the field of cybersecurity, the current Vice President of Information Technology’s background includes in-depth knowledge and experience in developing and executing the Company’s cybersecurity strategies. They oversee the Company’s IT governance programs; test compliance with internal, industry and regulatory standards; remediate known risks; and lead the Company’s employee training program. The current Director of Cybersecurity has over 30 years of experience in information technology across a variety of industries and compliance programs. The Director of Cybersecurity has been heavily focused on cybersecurity in regulated industries for over 10 years.
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block]	The Vice President of Information Technology and Director of Cybersecurity are kept informed about the latest developments in cybersecurity, including emerging threats and innovative risk management techniques. They implement and oversee processes for the regular monitoring of the Company’s information systems. This includes the deployment of advanced security measures and regular system audits to identify potential vulnerabilities. In the event of a cybersecurity incident, the Company is equipped with a defined and practiced incident response plan, which includes incident response retainers from respected third parties. This plan includes immediate actions to mitigate the impact of the incident, long-term strategies for remediation and the prevention of future incidents.
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag]	true

Investments Accounted for by the Equity Method and Variable Interest Entities

12 Months Ended

Dec. 31, 2025

Equity Method Investments and Joint Ventures [Abstract]

Investments Accounted for by the Equity Method and Variable Interest Entities

Equity Method Investments

The following table reflects the Company’s equity investments in unconsolidated affiliates as of December 31, 2025:


Name	Economic Interest	Investment Balance (a)
		(In millions)
Avenal	50%	$	12
Desert Sunlight	25%	212
Elkhorn Ridge	66.7%	(3)
GenConn (b)	50%	72
San Juan Mesa	75%	(2)
		$	291

(a) The Company’s maximum exposure to loss is limited to its investment balances.

(b) GenConn is a VIE.

As of December 31, 2025 and 2024, the Company had $25 million and $20 million, respectively, of undistributed earnings from its equity method investments.

The Company acquired its interest in Desert Sunlight on June 30, 2015, for $285 million, which resulted in a $181 million difference between the purchase price and the basis of the acquired assets and liabilities. The difference is attributable to the fair value of the property, plant and equipment and PPAs. The Company is amortizing the related basis differences to equity in earnings of unconsolidated subsidiaries over the related useful life of the underlying assets acquired. As of December 31, 2025, the carrying value of the basis difference is $109 million.

The Company’s pro-rata share of non-recourse debt held by unconsolidated affiliates was $259 million as of December 31, 2025.

Rosie Central BESS — On June 13, 2024, when the Rosamond Central BESS facility reached substantial completion, Clearway Renew redeemed Rosie Class B LLC’s entire investment of $28 million in Rosie Central BESS utilizing the additional purchase price paid by the Company, as further described in Note 3, Acquisitions and Dispositions. Rosie Class B LLC’s equity investment in Rosie Central BESS was comprised of contributions from the Company and the third-party cash equity investor in Rosie TargetCo LLC during the year ended December 31, 2023. The Company previously accounted for its investment in Rosie Central BESS as an equity method investment.

The following tables present summarized financial information for the Company’s equity method investments:


	Year Ended December 31,
	2025		2024		2023
Income Statement Data:	(In millions)




Desert Sunlight
Operating revenues	$	205	$	206	$	202
Operating income	149		146		144
Net income	118		113		108












Other (a)
Operating revenues	96		95		94
Operating income	31		25		23
Net income	22		16		13
			As of December 31,
			2025		2024
Balance Sheet Data:			(In millions)





Desert Sunlight
Current assets			$	77	$	81
Non-current assets			1,025		1,086
Current liabilities			66		63
Non-current liabilities			653		726

















Other (a)
Current assets			72		63
Non-current assets			358		391
Current liabilities			33		27
Non-current liabilities			208		225

(a) Includes Avenal, Elkhorn Ridge, GenConn and San Juan Mesa.

Variable Interest Entities, or VIEs

Entities that are Consolidated

The Company has a controlling financial interest in certain entities which have been identified as VIEs under ASC 810, Consolidations. These arrangements are primarily related to tax equity arrangements entered into with third parties in order to monetize certain tax credits associated with wind, solar and BESS facilities. The Company also has a controlling financial interest in certain partnership arrangements with third-party investors, which also have been identified as VIEs. Under the Company’s arrangements that have been identified as VIEs, the third-party investors are allocated earnings, tax attributes and distributable cash in accordance with the respective limited liability company agreements. Many of these arrangements also provide a mechanism to facilitate achievement of the investor’s specified return by providing incremental cash distributions to the investor at a specified date if the specified return has not yet been achieved.

The following is a summary of significant activity during 2025 related to the Company’s consolidated VIEs:

Honeycomb TE HoldCo LLC — As described in Note 3, Acquisitions and Dispositions, on October 15, 2025, Honeycomb 1 Holdco LLC, an indirect subsidiary of the Company, acquired Honeycomb TargetCo. Honeycomb TargetCo consolidates as primary beneficiary, and through its ownership of the Class B membership interests, Honeycomb TE HoldCo LLC, a tax equity fund that owns the Honeycomb Portfolio BESS facilities. The Class A membership interests in Honeycomb TE HoldCo LLC are held by a tax equity investor and are reflected as redeemable noncontrolling interest on the Company’s consolidated balance sheet, as the tax equity arrangement provides the tax equity investor with the right to redeem their interests in the partnership for cash or other assets at a point in time.

DGPV Funds — On August 11, 2025, Puma Class B LLC, an indirect subsidiary of the Company, acquired 100% of the Class A membership interests in Golden Puma Fund LLC, a tax equity fund that owns several distributed solar facilities, from the tax equity investor for $3 million. Prior to the acquisition, the Company consolidated Golden Puma Fund LLC through its ownership of the Class B membership interests and role as managing member, and the Class A membership interests were reflected as noncontrolling interest on the Company’s consolidated balance sheet. The difference between the historical cost of the Company’s noncontrolling interest and the cash paid to acquire the Class A membership interests was less than $1 million.

Pine Forest TargetCo — As described in Note 3, Acquisitions and Dispositions, on June 10, 2025, Pine Forest CE Class A Owner LLC, an indirect subsidiary of the Company, acquired the Class A membership interests in Pine Forest TargetCo, which is a partnership. The Company consolidates Pine Forest TargetCo as a VIE, as the Company is the primary beneficiary. Through its membership interests in Pine Forest TargetCo, the Company receives 50% of distributable cash. The Company recorded the third-party cash equity investor’s noncontrolling interest in Pine Forest TargetCo at the historical carrying amount, with the offset to contributed capital. Pine Forest TargetCo consolidates as primary beneficiary, and through its ownership of the Class B membership interests, Pine Forest TE HoldCo LLC, a tax equity fund that directly owns the Pine Forest solar and BESS facility. The Class A membership interests in Pine Forest TE HoldCo LLC are held by Pine Forest TE Class A, an indirect subsidiary of Clearway, Inc., and are reflected as noncontrolling interest on the Company’s consolidated balance sheet.

Luna Valley TE Holdco LLC — As described in Note 3, Acquisitions and Dispositions, on April 29, 2025, LV-Daggett Parent Holdco LLC, an indirect subsidiary of the Company, acquired Luna Valley Class B. Luna Valley Class B consolidates as primary beneficiary, and through its ownership of the Class B membership interests, Luna Valley TE Holdco LLC, a tax equity fund that owns the Luna Valley solar facility. The Class A membership interests in Luna Valley TE Holdco LLC are held by a tax equity investor and are reflected as redeemable noncontrolling interest on the Company’s consolidated balance sheet, as the tax equity arrangement provides the tax equity investor with the right to redeem their interests in the partnership for cash or other assets at a point in time.

Daggett 1 TE Holdco LLC — As described in Note 3, Acquisitions and Dispositions, on April 29, 2025, LV-Daggett Parent Holdco LLC acquired Daggett 1 Class B. Daggett 1 Class B consolidates as primary beneficiary, and through its ownership of the Class B membership interests, Daggett 1 TE Holdco LLC, a tax equity fund that owns the Daggett 1 BESS facility. The Class A membership interests in Daggett 1 TE Holdco LLC are held by a tax equity investor and are reflected as redeemable noncontrolling interest on the Company’s consolidated balance sheet, as the tax equity arrangement provides the tax equity investor with the right to redeem their interests in the partnership for cash or other assets at a point in time.

Rosie South TargetCo — As described in Note 3, Acquisitions and Dispositions, on March 20, 2025, Rosamond South Investment LLC, an indirect subsidiary of the Company, acquired the Class A membership interests in Rosie South TargetCo, which is a partnership. The Company consolidates Rosie South TargetCo as a VIE, as the Company is the primary beneficiary. Through its membership interests in Rosie South TargetCo, the Company receives 50% of distributable cash. The Company recorded the third-party cash equity investor’s noncontrolling interest in Rosie South TargetCo at the historical carrying amount, with the offset to contributed capital. Rosie South TargetCo consolidates as primary beneficiary, and through its ownership of the Class B membership interests, Rosie South TE Holdco LLC, a tax equity fund that directly owns the Rosamond South I solar and BESS facility. The Class A membership interests in Rosie South TE Holdco LLC are held by a tax equity investor and are reflected as noncontrolling interest on the Company’s consolidated balance sheet.

The Company has updated the following disclosure of assets and liabilities for its consolidated VIEs to present combined totals, and has revised the amounts as of December 31, 2024 to reflect accurate comparative totals for the same relevant entities:


(In millions)	December 31, 2025		December 31, 2024
Other current and non-current assets	$	1,031	$	755
Property, plant and equipment	7,894		5,985
Total assets	$	8,925	$	6,740
Total liabilities	$	2,594	$	1,858

Revision of Previously Issued Unaudited Financial Information (Unaudited) - Summary of Corrections to the Impacted Financial Statement Line Items (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2025	Jun. 30, 2025	Mar. 31, 2025	Jun. 30, 2025	Sep. 30, 2025	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	$ (316)	$ (45)	$ (99)	$ (144)	$ (460)	$ (555)	$ (236)	$ (162)
Net income (loss) attributable to Clearway Energy LLC	345	64	(5)	59	404	384	203	149
Comprehensive income (loss) attributable to redeemable noncontrolling interests	(316)	(46)	(101)	(147)	(463)	(557)	(233)	(163)
Comprehensive income (loss) attributable to Clearway Energy LLC	340	48	(9)	39	379	381	195	143
Redeemable noncontrolling interest in subsidiaries	104	45		45	104	103	0
Retained earnings	1,016	761	802	761	1,016	875	894
Noncontrolling interest	4,149	4,162	3,863	4,162	4,149	4,419	3,829
Total Members’ Equity	5,667	5,568	5,479	5,568	5,667
Net income (loss)						49	(46)	(30)
Retained Earnings
Total Members’ Equity	1,016	761	802	761	1,016
Net income (loss)	345	64	(5)			384	203	149
Noncontrolling Interest
Total Members’ Equity	4,149	4,162	3,863	4,162	4,149	4	8	5
Net income (loss)	(154)	(39)	(99)			$ (335)	$ (249)	$ (179)
As Previously Reported
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	(322)	(50)	(111)	(161)	(483)
Net income (loss) attributable to Clearway Energy LLC	351	69	7	76	427
Comprehensive income (loss) attributable to redeemable noncontrolling interests	(322)	(51)	(113)	(164)	(486)
Comprehensive income (loss) attributable to Clearway Energy LLC	346	53	3	56	402
Redeemable noncontrolling interest in subsidiaries	74	38		38	74
Retained earnings	1,039	778	814	778	1,039
Noncontrolling interest	4,156	4,152	3,851	4,152	4,156
Total Members’ Equity	5,697	5,575	5,479	5,575	5,697
As Previously Reported \| Retained Earnings
Total Members’ Equity	1,039	778	814	778	1,039
Net income (loss)	351	69	7
As Previously Reported \| Noncontrolling Interest
Total Members’ Equity	4,156	4,152	3,851	4,152	4,156
Net income (loss)	(137)	(37)	(111)
Adjustments
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	6	5	12	17	23
Net income (loss) attributable to Clearway Energy LLC	(6)	(5)	(12)	(17)	(23)
Comprehensive income (loss) attributable to redeemable noncontrolling interests	6	5	12	17	23
Comprehensive income (loss) attributable to Clearway Energy LLC	(6)	(5)	(12)	(17)	(23)
Redeemable noncontrolling interest in subsidiaries	30	7		7	30
Retained earnings	(23)	(17)	(12)	(17)	(23)
Noncontrolling interest	(7)	10	12	10	(7)
Total Members’ Equity	(30)	(7)	0	(7)	(30)
Adjustments \| Retained Earnings
Total Members’ Equity	(23)	(17)	(12)	(17)	(23)
Net income (loss)	(6)	(5)	(12)
Adjustments \| Noncontrolling Interest
Total Members’ Equity	(7)	10	12	$ 10	$ (7)
Net income (loss)	$ (17)	$ (2)	$ 12

Contingencies	12 Months Ended
Contingencies	Dec. 31, 2025
Commitments and Contingencies Disclosure [Abstract]
Contingencies	Contingencies The Company records reserves 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 will establish an adequate reserve for ongoing legal matters. In addition, legal costs are expensed as incurred. Management assesses such matters based on current information and makes a judgment concerning its potential outcome, considering the nature of the claim, the amount and nature of damages sought and the probability of success. The Company is unable to predict the outcome of ongoing 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 estimate of 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 reserves and that such difference could be material. The Company and its subsidiaries are party to 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 the Company’s consolidated financial position, results of operations or cash flows.

Investments Accounted for by the Equity Method and Variable Interest Entities - Narrative (Details) - USD ($) $ in Millions			12 Months Ended
	Aug. 11, 2025	Jun. 30, 2015	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Jun. 10, 2025	Mar. 20, 2025	Jun. 13, 2024
Schedule of Equity Method Investments [Line Items]
Retained earnings, undistributed earnings from equity method investees			$ 25	$ 20
Payments to acquire equity method investments			0	0	$ 28
Long-term debt			8,680
Equity investments in affiliates			291	$ 309
Desert Sunlight
Schedule of Equity Method Investments [Line Items]
Business acquisition, consideration transferred, working capital		$ 181
Desert Sunlight
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments		$ 285
Carrying value basis difference			109
Long-term debt			259
Equity investments in affiliates			$ 212
Ownership interest (as a percentage)			25.00%
Rosie Central BESS
Schedule of Equity Method Investments [Line Items]
Equity investments in affiliates								$ 28
Golden Puma Fund LLC
Schedule of Equity Method Investments [Line Items]
Equity investments in affiliates	$ 3
Ownership interest (as a percentage)	100.00%
Payments to acquire business	$ 1
Pine Forest CE TargetCo
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percentage)						50.00%
Rosie South
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percentage)							50.00%

Intangible Assets

12 Months Ended

Dec. 31, 2025

Goodwill and Intangible Assets Disclosure [Abstract]

Intangible Assets

Intangible Assets — The Company’s intangible assets as of December 31, 2025 and 2024 primarily reflect intangible assets established from its business acquisitions and are comprised of the following:

•PPAs — Established predominantly with the acquisitions of the Alta Wind Portfolio, Tapestry, Laredo Ridge, Carlsbad Energy Center, Agua Caliente, the Utah Solar Portfolio, the Capistrano Wind Portfolio, Tuolumne and Catalina. These represent the fair value of the PPAs acquired. These are amortized on a straight-line basis, over the term of the PPA.

•Leasehold Rights — Established with the acquisition of the Alta Wind Portfolio, this represents the fair value of contractual rights to receive royalty payments equal to a percentage of PPA revenue from certain facilities. These are amortized as a reduction to operating revenue on a straight-line basis over the term of the PPAs.

•Emission Allowances — These intangibles primarily consist of SO2 and NOx emission allowances established with the El Segundo, Walnut Creek and Carlsbad Energy Center acquisitions. These emission allowances are held-for-use and are amortized to cost of operations, with NOx allowances amortized on a straight-line basis and SO2 allowances amortized based on units of production.

•Other — Consists of a) the acquisition date fair value of the contractual rights to a ground lease for South Trent and to utilize certain interconnection facilities for Blythe as well as land rights acquired in connection with the acquisition of Elbow Creek; b) development rights related to certain solar business acquisitions; c) purchased software for certain solar facilities; d) RECs acquired in connection with the acquisition of the Utah Solar Portfolio; and e) favorable land leases acquired in connection with the acquisition of the Utah Solar Portfolio.

The following tables summarize the components of intangible assets subject to amortization:


Year ended December 31, 2025	PPAs		Leasehold Rights		Emission Allowances		Other		Total
(In millions)
January 1, 2025	$	3,265	$	86	$	17	$	19	$	3,387
Acquisitions (a)	351		—		—		—		351
Other	—		—		—		4		4

December 31, 2025	3,616		86		17		23		3,742
Less accumulated amortization	(1,322)		(46)		(6)		(8)		(1,382)
Net carrying amount	$	2,294	$	40	$	11	$	15	$	2,360

(a) The weighted average life of acquired intangibles was 14 years for PPAs.


Year ended December 31, 2024	PPAs		Leasehold Rights		Emission Allowances		Other		Total
(In millions)
January 1, 2024	$	3,265	$	86	$	17	$	15	$	3,383

Other	—		—		—		4		4
December 31, 2024	3,265		86		17		19		3,387
Less accumulated amortization	(1,140)		(42)		(5)		(7)		(1,194)
Net carrying amount	$	2,125	$	44	$	12	$	12	$	2,193

The Company recorded amortization expense of $189 million, $184 million and $186 million during the years ended December 31, 2025, 2024 and 2023, respectively. Of these amounts, $183 million, $178 million and $181 million during the years ended December 31, 2025, 2024 and 2023, respectively, were related to the amortization of intangible assets for PPAs and were recorded to contract amortization expense, which reduced operating revenues in the consolidated statements of operations. The Company estimates the amortization expense for its intangibles for each of the next five years will be $200 million.

Long-term Debt - Schedule of Long-Term Debt (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024
Debt Instrument [Line Items]
Total debt	$ 8,680	$ 7,235
Less current maturities	(714)	(430)
Less net debt issuance costs	(70)	(57)
Add premiums	2	2
Total long-term debt	7,898	6,750
Intercompany Note with Clearway, Inc.
Debt Instrument [Line Items]
Total debt	$ 6	0
Interest rate, (in percentage)	3.61%
Senior Notes
Debt Instrument [Line Items]
Total debt	$ 2,125	2,125
Senior Notes \| Minimum
Debt Instrument [Line Items]
Interest rate, (in percentage)	3.75%
Senior Notes \| Maximum
Debt Instrument [Line Items]
Interest rate, (in percentage)	4.75%
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility
Debt Instrument [Line Items]
Total debt	$ 361	0
Basis spread on variable rate	1.75%
Fixed Rate
Debt Instrument [Line Items]
Total debt	$ 3,001	3,190
Fixed Rate \| Minimum
Debt Instrument [Line Items]
Basis spread on fixed rate	2.339%
Fixed Rate \| Maximum
Debt Instrument [Line Items]
Basis spread on fixed rate	8.00%
Variable Rate
Debt Instrument [Line Items]
Total debt	$ 3,187	$ 1,920
Variable Rate \| Minimum
Debt Instrument [Line Items]
Basis spread on variable rate	1.375%
Variable Rate \| Maximum
Debt Instrument [Line Items]
Basis spread on variable rate	2.75%

Property, Plant and Equipment - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 16,269	$ 14,030
Accumulated depreciation	(4,673)	(4,086)
Net property, plant and equipment	11,596	9,944
Facilities and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 15,095	13,302
Facilities and equipment \| Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	3 years
Facilities and equipment \| Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	40 years
Land and improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 644	537
Construction in progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment	530	191
Construction in progress \| Accrued Liabilities
Property, Plant and Equipment [Line Items]
Property, plant and equipment	12	9
Construction in progress \| Flexible Generation
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 24	$ 23

Asset Impairments	12 Months Ended
Asset Impairments	Dec. 31, 2025
Asset Impairments [Abstract]
Asset Impairments	Asset Impairments 2023 Impairment Losses During the fourth quarter of 2023, in preparation and review of its annual budget, the Company updated its long-term estimates of operating and capital expenditures and revised its assessment of long-term merchant power prices, which was primarily informed by present conditions and did not contemplate future policy changes, which could impact renewable energy power prices. The impairment analysis reviews certain qualitative factors as well as the results of long-term operating expectations and its carrying value to determine if impairment indicators are present. The impairment analysis indicated that the projected future cash flows for certain facilities within the Renewables & Storage segment no longer supported the recoverability of the carrying value of the related long-lived assets. As such, the Company recorded an impairment loss of $12 million, which primarily related to property, plant, and equipment to reflect the assets at fair market value. The fair value of the facilities was determined using an income approach by applying a discounted cash flow methodology to the updated long-term budgets for each respective plant. The income approach included key inputs such as forecasted merchant power prices, operations and maintenance expense, and discount rates. The resulting fair value is a Level 3 fair value measurement.

Schedule I - Condensed Financial Statements - CF (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Condensed Cash Flow Statements, Captions [Line Items]
Net Cash Provided by (Used in) Operating Activities	$ 680	$ 772	$ 733
Net Cash Used in Investing Activities	(825)	(725)	(523)
Proceeds from the issuance of Class C units	48	0	0
Net Cash Provided by (Used in) Financing Activities	230	(365)	(155)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	85	(318)	55
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	733	1,051	996
Cash, Cash Equivalents and Restricted Cash at End of Period	818	733	1,051
Clearway Energy LLC
Condensed Cash Flow Statements, Captions [Line Items]
Net Cash Provided by (Used in) Operating Activities	3	11	23
Investments in consolidated affiliates	210	52	209
Net Cash Used in Investing Activities	210	52	209
(Transfer) receipt of funds under intercompany cash management arrangement	(3)	0	4
Tax-related distributions	0	(2)	(51)
Payments of distributions	358	334	311
Net Cash Provided by (Used in) Financing Activities	(313)	(336)	(358)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(100)	(273)	(126)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	137	410	536
Cash, Cash Equivalents and Restricted Cash at End of Period	37	137	410
Clearway Energy LLC \| Common Class C
Condensed Cash Flow Statements, Captions [Line Items]
Proceeds from the issuance of Class C units	$ 48	$ 0	$ 0

Summary of Significant Accounting Policies - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Summary of Significant Accounting Policies [Line Items]
Other cash and cash equivalents	$ 194	$ 194
Restricted cash	587	401
Allowance for credit losses	0	0
Interest costs capitalized	51	28	$ 36
Deferred tax expense (benefit)	(1)	1
Deferred tax liability	2	3
Contingent rental income	797	831	$ 780
Long-Term Debt, Current
Summary of Significant Accounting Policies [Line Items]
Restricted cash	99	37
Debt Service Obligations
Summary of Significant Accounting Policies [Line Items]
Restricted cash	85	102
Cash Distribution
Summary of Significant Accounting Policies [Line Items]
Restricted cash	257	78
Cash Distribution \| Rosie South TargetCo LLC
Summary of Significant Accounting Policies [Line Items]
Restricted cash	174
Operating Funds
Summary of Significant Accounting Policies [Line Items]
Restricted cash	$ 146	$ 184

Long-term Debt - Schedule of Annual Payments Based on the Maturities of NRG Yield's Debt (Details) $ in Millions	Dec. 31, 2025 USD ($)
Debt Disclosure [Abstract]
2026	$ 1,145
2027	364
2028	2,022
2029	863
2030	995
Thereafter	3,291
Total	8,680
Current debt	$ 431

- Definition

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

+ References

+ Details

Segment Reporting

12 Months Ended

Dec. 31, 2025

Segment Reporting [Abstract]

Segment Reporting

The Company’s segment structure reflects how management currently operates and allocates resources. The Company’s businesses are segregated based on Flexible Generation and Renewables & Storage businesses, which consist of solar, wind and battery energy storage system, or BESS, facilities. The Corporate segment reflects the Company’s corporate costs and includes eliminating entries. The Company’s chief operating decision maker, its Chief Executive Officer, evaluates the performance of its segments based on net income (loss). The Company’s Chief Executive Officer reviews net income (loss) and its components on a monthly and quarterly basis to evaluate the performance of each segment and to determine how to allocate resources.

Approximately 58% of the Company’s operating revenues and 45% of the Company’s assets relate to operations located in California. Also, the Company generated more than 10% of its revenues from the following customers for the years ended December 31, 2025, 2024 and 2023:


	2025		2024		2023
Customer	Flexible Generation	Renewables & Storage	Flexible Generation	Renewables & Storage	Flexible Generation	Renewables & Storage
SCE	7%	15%	7%	17%	11%	13%
PG&E	2%	14%	3%	14%	4%	13%


	Year ended December 31, 2025
(In millions)	Flexible Generation		Renewables & Storage		Corporate (a)		Total
Operating revenues	$	291	$	1,138	$	—	$	1,429
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below	109		419		—		528
Depreciation, amortization and accretion	112		570		—		682

General and administrative	—		—		40		40
Transaction and integration costs	—		—		16		16

Operating income (loss)	70		149		(56)		163
Equity in earnings of unconsolidated affiliates	1		30		—		31


Other income, net	4		22		3		29
Loss on debt extinguishment	—		(8)		—		(8)
Interest expense	(35)		(252)		(100)		(387)
Income (loss) before income taxes	40		(59)		(153)		(172)
Income tax benefit	—		(1)		—		(1)
Net Income (Loss)	40		(58)		(153)		(171)

Less: Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	—		(555)		—		(555)
Net Income (Loss) Attributable to Clearway Energy LLC	$	40	$	497	$	(153)	$	384
Balance Sheet
Equity investments in affiliates	$	72	$	219	$	—	$	291
Capital expenditures (b)	9		187		—		196
Total Assets	$	1,803	$	14,557	$	84	$	16,444

(a) Includes eliminations.

(b) Includes accruals.


	Year ended December 31, 2024
(In millions)	Flexible Generation		Renewables & Storage		Corporate (a)		Total
Operating revenues	$	342	$	1,029	$	—	$	1,371
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below	137		367		(3)		501
Depreciation, amortization and accretion	115		512		—		627

General and administrative	—		—		38		38
Transaction and integration costs	—		—		8		8

Operating income (loss)	90		150		(43)		197


Equity in earnings of unconsolidated affiliates	3		32		—		35


Other income, net	6		31		11		48
Loss on debt extinguishment	—		(5)		—		(5)
Interest expense	(35)		(176)		(96)		(307)
Income (loss) before income taxes	64		32		(128)		(32)
Income tax expense	—		1		—		1
Net Income (Loss)	64		31		(128)		(33)
Less: Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	—		(236)		—		(236)
Net Income (Loss) Attributable to Clearway Energy LLC	$	64	$	267	$	(128)	$	203
Balance Sheet
Equity investments in affiliates	$	75	$	234	$	—	$	309
Capital expenditures (b)	9		179		—		188
Total Assets	$	1,933	$	12,236	$	151	$	14,320

(a) Includes eliminations.

(b) Includes accruals.


	Year ended December 31, 2023
(In millions)	Flexible Generation		Renewables & Storage		Corporate (a)		Total
Operating revenues	$	420	$	894	$	—	$	1,314
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below	154		321		(2)		473
Depreciation, amortization and accretion	129		397		—		526
Impairment losses	—		12		—		12
General and administrative	—		—		35		35
Transaction and integration costs	—		—		4		4

Operating income (loss)	137		164		(37)		264
Equity in earnings of unconsolidated affiliates	3		9		—		12


Other income, net	4		24		24		52
Loss on debt extinguishment	—		(6)		—		(6)
Interest expense	(35)		(205)		(97)		(337)
Income (loss) before income taxes	109		(14)		(110)		(15)
Income tax benefit	—		(2)		—		(2)
Net Income (Loss)	109		(12)		(110)		(13)
Less: Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	—		(162)		—		(162)
Net Income (Loss) Attributable to Clearway Energy LLC	$	109	$	150	$	(110)	$	149

(a) Includes eliminations.

- 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
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 21
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482810/280-10-50-21

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 21
-Subparagraph (a)
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+ Details

Schedule I - Condensed Financial Statements

12 Months Ended

Dec. 31, 2025

Condensed Financial Information Disclosure [Abstract]

Condensed Financial Statements

Clearway Energy LLC (Parent)

Condensed Financial Statements

Condensed Statements of Operations


	Year ended December 31,
(In millions)	2025		2024		2023

Equity in earnings of consolidated subsidiaries	$	381	$	192	$	126




Interest income	3		11		23
Total other income	384		203		149





Net Income Attributable to Clearway Energy LLC	$	384	$	203	$	149

Clearway Energy LLC (Parent)

Condensed Balance Sheets


	December 31,		December 31,
	2025		2024
ASSETS	(In millions)
Current Assets
Cash and cash equivalents	$	37	$	137


Accounts receivable — affiliates	1		—



Other current assets	—		1

Other Assets
Investment in consolidated subsidiaries	1,470		1,679




Total Assets	$	1,508	$	1,817
LIABILITIES AND MEMBERS’ EQUITY
Current Liabilities


Accounts payable — affiliates	$	1	$	4



Other Liabilities



Other non-current liabilities	1		1
Total Liabilities	2		5
Commitments and Contingencies
Members’ Equity
Contributed capital	641		911
Retained earnings	875		894
Accumulated other comprehensive (loss) income	(10)		7

Total Members’ Equity	1,506		1,812
Total Liabilities and Members’ Equity	$	1,508	$	1,817

Clearway Energy LLC (Parent)

Condensed Statements of Cash Flows


	Years ended December 31,
	2025		2024		2023
	(In millions)
Cash Flows from Operating Activities
Net Cash Provided by Operating Activities	$	3	$	11	$	23
Cash Flows from Investing Activities
Investments in consolidated affiliates	210		52		209

Net Cash Provided by Investing Activities	210		52		209
Cash Flows from Financing Activities
(Transfer) receipt of funds under intercompany cash management arrangement	(3)		—		4

Proceeds from issuance of Class C units	48		—		—


Tax-related distributions	—		(2)		(51)
Payments of distributions	(358)		(334)		(311)
Net Cash Used in Financing Activities	(313)		(336)		(358)
Net Decrease in Cash and Cash Equivalents	(100)		(273)		(126)
Cash and Cash Equivalents at Beginning of Period	137		410		536
Cash and Cash Equivalents at End of Period	$	37	$	137	$	410

Background and Basis of Presentation

Background

Clearway Energy LLC, together with its consolidated subsidiaries, or the Company, is an energy infrastructure investor with a focus on investments in clean energy and owner of modern, sustainable and long-term contracted assets across North America. The Company is sponsored by Clearway Energy Group LLC, or CEG.

The Company is one of the largest owners of clean energy generation assets in the U.S. The Company’s portfolio comprises approximately 12.9 GW of gross capacity in 27 states, including approximately 10.1 GW of wind, solar and battery energy storage systems, or BESS, and approximately 2.8 GW of dispatchable combustion-based power generation assets included in the Flexible Generation segment that provide critical grid reliability services. Through this environmentally-sound, diversified and primarily contracted portfolio, the Company endeavors to provide its unit holders with stable and growing distributions. The majority of the Company’s revenues are derived from long-term contractual arrangements for the output or capacity from these assets.

Clearway Energy, Inc., or Clearway, Inc., consolidates the results of the Company through its controlling interest, with CEG’s interest shown as contributed capital in the Company’s consolidated financial statements. The holders of Clearway, Inc.’s outstanding shares of Class A and Class C common stock are entitled to dividends as declared. CEG receives its distributions from the Company through its ownership of the Company’s Class B and Class D units. From time to time, CEG may also hold shares of Clearway, Inc.’s Class A and/or Class C common stock.

As of December 31, 2025, Clearway, Inc. owned 58.62% of the economic interests of the Company, with CEG owning 41.38% of the economic interests of the Company. For further discussion, see Note 11, Members’ Equity.

Basis of Presentation

The condensed parent-only company financial statements have been prepared in accordance with Rule 12-04 of Regulation S-X, as the restricted net assets of Clearway Energy LLC’s subsidiaries exceed 25% of the consolidated net assets of Clearway Energy LLC. The parent’s 100% investment in its subsidiaries has been recorded using the equity basis of accounting in the accompanying condensed parent-only financial statements. These statements should be read in conjunction with the consolidated financial statements and notes thereto of Clearway Energy LLC.

Note 2 — Long-Term Debt

For a discussion of Clearway Energy LLC’s financing arrangements, see Note 10, Long-term Debt, to the Company’s consolidated financial statements.

Note 3 — Contingencies and Guarantees

See Note 14, Contingencies, to the Company’s consolidated financial statements for a detailed discussion of Clearway Energy LLC’s contingencies.

Note 4 — Distributions

Cash distributions paid on the Company’s Class A, Class B, Class C and Class D units, were $358 million, $334 million, and $311 million for the years ended December 31, 2025, 2024, and 2023, respectively.

Insider Trading Policies and Procedures	12 Months Ended
Insider Trading Policies and Procedures	Dec. 31, 2025
Insider Trading Policies and Procedures [Line Items]
Insider Trading Policies and Procedures Adopted	true

Acquisitions and Dispositions - Narrative (Details) $ in Millions	Dec. 17, 2025 USD ($)	Oct. 15, 2025 USD ($) renewalOption MW	Oct. 02, 2025 USD ($) MW	Sep. 19, 2025 USD ($)	Sep. 04, 2025 USD ($)	Aug. 13, 2025 USD ($)	Jul. 16, 2025 USD ($) MW	Jun. 10, 2025 USD ($) MW	May 21, 2025 USD ($)	Apr. 29, 2025 USD ($) MW	Mar. 20, 2025 USD ($) MW	Nov. 18, 2024 USD ($) MW	Apr. 16, 2024 USD ($) MW	Mar. 15, 2024 USD ($) MW	Dec. 01, 2023 USD ($) MW	Oct. 31, 2023 USD ($) MW
Pine Forest Drop Down \| Cash Equity Investor
Business Acquisition [Line Items]
Expected contributions upon substantial completion	$ 144
Daggett 1 Drop Down \| CEG
Business Acquisition [Line Items]
Net assets acquired less noncontrolling interest				$ 33
Luna Valley Drop Down \| CEG
Business Acquisition [Line Items]
Expected contributions upon substantial completion					$ 50
Rosamond South I Drop Down
Business Acquisition [Line Items]
Power purchase agreement period (in years)											15 years
Net assets acquired less noncontrolling interest											$ 3
Rosamond South I Drop Down \| Clearway Renew LLC \| Rosamond South Investment LLC
Business Acquisition [Line Items]
Current assets, receivables						$ 29
Rosamond South I Drop Down \| Cash Equity Investor
Business Acquisition [Line Items]
Payments for asset acquisition											2
Rosamond South I Drop Down \| Cash Equity Investor \| Clearway Renew LLC \| Rosamond South Investment LLC
Business Acquisition [Line Items]
Current assets, receivables						41
Rosamond South I Drop Down \| Rosie South
Business Acquisition [Line Items]
Payments for asset acquisition						33
Rosamond South I Drop Down \| CEG
Business Acquisition [Line Items]
Net assets acquired less noncontrolling interest						$ 53
Payments to fund project reserve accounts											$ 3
Dan’s Mountain Drop Down
Business Acquisition [Line Items]
Net assets acquired less noncontrolling interest												$ 2
Dan’s Mountain Drop Down \| Dan’s Mountain Parent Holdco LLC
Business Acquisition [Line Items]
Current assets, receivables												$ 36
Power purchase agreement period (in years)												12 years
Asset acquisition, adjustment to contributed capital												$ 1
Dan’s Mountain Drop Down \| Cash Equity Investor
Business Acquisition [Line Items]
Expected contributions upon substantial completion									$ 45
Dan’s Mountain Drop Down \| Dan’s Mountain TargetCo
Business Acquisition [Line Items]
Payments for asset acquisition									43
Dan’s Mountain Drop Down \| CEG
Business Acquisition [Line Items]
Net assets acquired less noncontrolling interest									$ 26
Rosamond Central Solar Project
Business Acquisition [Line Items]
Net assets acquired less noncontrolling interest															$ 266
Rosamond Central Solar Project \| Rosie Central BESS
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW															147
Payments for asset acquisition															$ 70
Current assets, receivables															$ 279
Power purchase agreement period (in years)															15 years
Rosamond Central Solar Project \| Rosie Central BESS \| Clearway Renew LLC
Business Acquisition [Line Items]
Payments for asset acquisition															$ 16
Current assets, receivables															64
Rosamond Central Solar Project \| Cash Equity Investor \| Rosie Central BESS
Business Acquisition [Line Items]
Payments for asset acquisition															54
Rosamond Central Solar Project \| Tax Equity Investors \| Rosie Central BESS
Business Acquisition [Line Items]
Current assets, receivables															$ 215
Victory Pass and Arica Drop Down
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW																200
Power generation storage capacity, megawatts \| MW																50
Power purchase agreement period (in years)																15 years
Net assets acquired less noncontrolling interest																$ (1)
Weighted average contract duration (in years)																14 years
Victory Pass and Arica Drop Down \| Clearway Renew LLC
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW																263
Power generation storage capacity, megawatts \| MW																136
Additional payments for asset acquisition																$ 165
Victory Pass and Arica Drop Down \| Cash Equity Investor \| Clearway Renew LLC
Business Acquisition [Line Items]
Additional payments for asset acquisition																347
Cedar Creek Drop Down
Business Acquisition [Line Items]
Net assets acquired less noncontrolling interest													$ 17
Texas Solar Nova 2 Drop Down
Business Acquisition [Line Items]
Net assets acquired less noncontrolling interest														$ 72
Texas Solar Nova 2 Drop Down \| Clearway Renew LLC
Business Acquisition [Line Items]
Payments for asset acquisition														17
Texas Solar Nova 2 Drop Down \| Cash Equity Investor \| TSN1 TE Holdco LLC
Business Acquisition [Line Items]
Payments for asset acquisition														95
Texas Solar Nova 2 Drop Down \| CEG
Business Acquisition [Line Items]
Payments to fund project reserve accounts														$ 9
Pine Forest CE Class A Owner LLC \| Pine Forest Drop Down
Business Acquisition [Line Items]
Payments for asset acquisition								$ 18
Power purchase agreement period (in years)								20 years
Net assets acquired less noncontrolling interest								$ 9
Pine Forest CE Class A Owner LLC \| Pine Forest Drop Down \| Pine Forest TargetCo
Business Acquisition [Line Items]
Payments for asset acquisition								68
Pine Forest CE Class A Owner LLC \| Pine Forest Drop Down \| Clearway Renew LLC \| Pine Forest TargetCo
Business Acquisition [Line Items]
Current assets, receivables								50
Pine Forest CE Class A Owner LLC \| Pine Forest Drop Down \| Clearway Renew LLC \| Pine Forest CE Class A Owner LLC
Business Acquisition [Line Items]
Current assets, receivables								38
Pine Forest CE Class A Owner LLC \| Pine Forest Drop Down \| Cash Equity Investor \| Clearway Renew LLC
Business Acquisition [Line Items]
Payments for asset acquisition								36
Current assets, receivables								144
Pine Forest TE Class A \| Pine Forest Drop Down
Business Acquisition [Line Items]
Payments for asset acquisition								$ 9
Honeycomb TE Holdco LLC \| Honeycomb Portfolio
Business Acquisition [Line Items]
Payments for asset acquisition		$ 78
Power purchase agreement period (in years)		20 years
Net assets acquired less noncontrolling interest		$ 2
Honeycomb TE Holdco LLC \| Honeycomb Portfolio \| Clearway Renew LLC
Business Acquisition [Line Items]
Current assets, receivables		62
LV-Daggett Parent Holdco LLC \| Daggett 1 Drop Down
Business Acquisition [Line Items]
Payments for asset acquisition		57		42
Power purchase agreement period (in years)										15 years
Net assets acquired less noncontrolling interest										$ 1
Payment For Asset Acquisitions, Adjustment		4
Payments for asset acquisition and transaction expenses				$ 42
LV-Daggett Parent Holdco LLC \| Luna Valley Drop Down
Business Acquisition [Line Items]
Payments for asset acquisition		119
Power purchase agreement period (in years)										17 years
Net assets acquired less noncontrolling interest										$ (7)
Payment For Asset Acquisitions, Adjustment		$ 29
LV-Daggett Parent Holdco LLC \| Luna Valley Drop Down \| LV-Daggett Parent Holdco LLC
Business Acquisition [Line Items]
Payments for asset acquisition and transaction expenses					$ 72					$ 72
Rosie South TargetCo LLC \| Rosamond South I Drop Down
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW											140
Power generation storage capacity, megawatts \| MW											117
Payments for asset acquisition											$ 4
Net assets acquired less noncontrolling interest											(3)
Rosie South TargetCo LLC \| Rosamond South I Drop Down \| Clearway Renew LLC
Business Acquisition [Line Items]
Payments for asset acquisition											$ 10
Catalina Solar Investment LLC \| Catalina Solar Acquisition
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW							109
Payments for asset acquisition							$ 127
Net assets acquired less noncontrolling interest							128
Payments for asset acquisition and transaction expenses							128
Washington Wind LLC \| Tuolumne
Business Acquisition [Line Items]
Power purchase agreement period (in years)										15 years
Net assets acquired less noncontrolling interest										$ 211
Payments for Asset Acquisition, Including Post Closing Transaction Expenses										$ 59
VP-Arica TargetCo LLC \| Victory Pass and Arica Drop Down \| Clearway Renew LLC
Business Acquisition [Line Items]
Payments for asset acquisition																46
VP-Arica TargetCo LLC \| Victory Pass and Arica Drop Down \| Cash Equity Investor \| Clearway Renew LLC
Business Acquisition [Line Items]
Payments for asset acquisition																$ 87
WV Wind HoldCo LLC \| Disposed of by Sale \| Mt. Storm Sale to Clearway Renew
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW			264
Power generation storage capacity, megawatts \| MW			335
Power purchase agreement period (in years)			20 years
Assets ownership sold (as a percentage)			100.00%
Disposal group, including discontinued operation, consideration			$ 152
Net assets transferred			51
WV Wind HoldCo LLC \| Clearway Renew LLC \| Disposed of by Sale \| Mt. Storm Sale to Clearway Renew
Business Acquisition [Line Items]
Disposal group, including discontinued operation, consideration			$ 336
Alternative Energy \| Pine Forest CE Class A Owner LLC \| Pine Forest Drop Down
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW								300
Power generation storage capacity, megawatts \| MW								200
Alternative Energy \| Honeycomb TE Holdco LLC \| Honeycomb Portfolio
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW		320
Payments for asset acquisition		$ 16
Power Purchase Agreement, Number of BESS Facilities \| renewalOption		4
Alternative Energy \| LV-Daggett Parent Holdco LLC \| Daggett 1 Drop Down
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW										114
Payments for asset acquisition										$ 11
Alternative Energy \| LV-Daggett Parent Holdco LLC \| Luna Valley Drop Down \| Luna Valley Class B
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW										200
Payments for asset acquisition										$ 18
Alternative Energy \| Catalina Solar Investment LLC \| Catalina Solar Acquisition
Business Acquisition [Line Items]
Payments for Asset Acquisition, Excluding Transaction Expenses							$ 1
Alternative Energy \| Dan’s Mountain Parent Holdco LLC \| Dan’s Mountain Drop Down \| Dan’s Mountain TargetCo LLC
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW												55
Alternative Energy \| Clearway Renew LLC \| Dan’s Mountain Drop Down \| Dan’s Mountain TargetCo LLC \| Dan’s Mountain Parent Holdco LLC
Business Acquisition [Line Items]
Payments for asset acquisition												$ 7
Alternative Energy \| Washington Wind LLC \| Tuolumne
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW										137
Payments for asset acquisition										$ 210
Payments for Asset Acquisition, Excluding Transaction Expenses										$ 1
Alternative Energy \| Cedar Creek Wind Holdco LLC \| Cedar Creek Drop Down \| Cedar Creek TE Holdco LLC
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW													160
Payments for asset acquisition													$ 117
Power purchase agreement period (in years)													25 years
Alternative Energy \| Lighthouse Renewable Holdco 2 LLC \| Texas Solar Nova 2 Drop Down \| TSN1 TE Holdco LLC
Business Acquisition [Line Items]
Power generation capacity, megawatts (over) \| MW														200
Payments for asset acquisition														$ 112
Power purchase agreement period (in years)														18 years

Accounting for Derivative Instruments and Hedging Activities - Schedule of Cash Flow Hedge Included in OCI (OCL) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Mark-to-market of cash flow hedge accounting contracts	$ (5)	$ (5)	$ (7)
Losses expected to be realized from OCL during the next 12 months	(6)
Accumulated Gain (Loss), Cash Flow Hedge, Including Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated OCI beginning balance	15	20	27
Accumulated (OCL) OCI ending balance	(6)	15	20
Accumulated Foreign Currency Adjustment Including Portion Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Reclassified from accumulated OCI to income due to realization of previously deferred amounts	(3)	(1)	(5)
Mark-to-market of cash flow hedge accounting contracts	(2)	(4)	(2)
Accumulated Foreign Currency Adjustment Including Portion Attributable to Noncontrolling Interest \| Rosamond South I Drop Down
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Drop Down	(4)	0	0
Accumulated Foreign Currency Adjustment Including Portion Attributable to Noncontrolling Interest \| Daggett 1 Drop Down
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Drop Down	(6)	0	0
Accumulated Foreign Currency Adjustment Including Portion Attributable to Noncontrolling Interest \| Luna Valley Drop Down
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Drop Down	(8)	0	0
Accumulated Foreign Currency Adjustment Including Portion Attributable to Noncontrolling Interest \| Pine Forest Drop Down
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Drop Down	5	0	0
Accumulated Foreign Currency Adjustment Including Portion Attributable to Noncontrolling Interest \| Honeycomb Portfolio Drop Down
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Drop Down	(3)	0	0
Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated OCI beginning balance	8	5
Accumulated (OCL) OCI ending balance	4	8	5
Noncontrolling Interest \| Rosamond South I Drop Down
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Drop Down	2
Clearway Energy LLC \| Rosamond South I Drop Down
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Drop Down	2
AOCI Including Portion Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated OCI beginning balance	7	15
Accumulated (OCL) OCI ending balance	$ (10)	$ 7	$ 15

Accounting for Derivative Instruments and Hedging Activities - Schedule of Fair Value of Derivative Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Derivatives, Fair Value [Line Items]
Derivative Assets	$ 156	$ 175
Derivative Liabilities	360	371
Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative Assets	31	27
Derivative Liabilities	27	0
Designated as Hedging Instrument \| Interest rate contracts current
Derivatives, Fair Value [Line Items]
Derivative Assets	2	5
Derivative Liabilities	6	0
Designated as Hedging Instrument \| Interest rate contracts long-term
Derivatives, Fair Value [Line Items]
Derivative Assets	29	22
Derivative Liabilities	21	0
Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative Assets	125	148
Derivative Liabilities	333	371
Not Designated as Hedging Instrument \| Interest rate contracts current
Derivatives, Fair Value [Line Items]
Derivative Assets	17	30
Derivative Liabilities	0	0
Not Designated as Hedging Instrument \| Interest rate contracts long-term
Derivatives, Fair Value [Line Items]
Derivative Assets	94	109
Derivative Liabilities	0	0
Not Designated as Hedging Instrument \| Energy-related commodity contracts current
Derivatives, Fair Value [Line Items]
Derivative Assets	10	4
Derivative Liabilities	46	56
Not Designated as Hedging Instrument \| Energy-related commodity contracts long-term
Derivatives, Fair Value [Line Items]
Derivative Assets	4	5
Derivative Liabilities	$ 287	$ 315

- Definition

Fair value, before effects of master netting arrangements, of a financial asset or other contract with one or more underlyings, notional amount or payment provision or both, and the contract can be net settled by means outside the contract or delivery of an asset. Includes assets elected not to be offset. Excludes assets not subject to a master netting arrangement.

+ References + Details

- Definition

Fair value, before effects of master netting arrangements, of a financial liability or contract with one or more underlyings, notional amount or payment provision or both, and the contract can be net settled by means outside the contract or delivery of an asset. Includes liabilities elected not to be offset. Excludes liabilities not subject to a master netting arrangement.

+ References + Details

Asset Impairments (Details) - USD ($) $ in Millions	12 Months Ended
Asset Impairments (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Asset Impairments [Abstract]
Impairment losses	$ 0	$ 0	$ 12

Fair Value of Financial Instruments - Schedule of Balance Sheet Grouping (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including current portion — affiliate	$ 8,680	$ 7,235
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including current portion — affiliate	6	0
Long-term debt, including current portion — external	8,676	7,237
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including current portion — affiliate	6	0
Long-term debt, including current portion — external	8,382	6,715
Fair Value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including current portion — external	2,038	1,922
Fair Value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including current portion — external	$ 6,350	$ 4,793

Segment Reporting (Tables)

12 Months Ended

Dec. 31, 2025

Segment Reporting [Abstract]

Schedule of Revenue by Major Customers by Reporting Segments

the Company generated more than 10% of its revenues from the following customers for the years ended December 31, 2025, 2024 and 2023:


	2025		2024		2023
Customer	Flexible Generation	Renewables & Storage	Flexible Generation	Renewables & Storage	Flexible Generation	Renewables & Storage
SCE	7%	15%	7%	17%	11%	13%
PG&E	2%	14%	3%	14%	4%	13%

Schedule of Segment Reporting Information, by Segment


	Year ended December 31, 2025
(In millions)	Flexible Generation		Renewables & Storage		Corporate (a)		Total
Operating revenues	$	291	$	1,138	$	—	$	1,429
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below	109		419		—		528
Depreciation, amortization and accretion	112		570		—		682

General and administrative	—		—		40		40
Transaction and integration costs	—		—		16		16

Operating income (loss)	70		149		(56)		163
Equity in earnings of unconsolidated affiliates	1		30		—		31


Other income, net	4		22		3		29
Loss on debt extinguishment	—		(8)		—		(8)
Interest expense	(35)		(252)		(100)		(387)
Income (loss) before income taxes	40		(59)		(153)		(172)
Income tax benefit	—		(1)		—		(1)
Net Income (Loss)	40		(58)		(153)		(171)

Less: Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	—		(555)		—		(555)
Net Income (Loss) Attributable to Clearway Energy LLC	$	40	$	497	$	(153)	$	384
Balance Sheet
Equity investments in affiliates	$	72	$	219	$	—	$	291
Capital expenditures (b)	9		187		—		196
Total Assets	$	1,803	$	14,557	$	84	$	16,444

(a) Includes eliminations.

(b) Includes accruals.


	Year ended December 31, 2024
(In millions)	Flexible Generation		Renewables & Storage		Corporate (a)		Total
Operating revenues	$	342	$	1,029	$	—	$	1,371
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below	137		367		(3)		501
Depreciation, amortization and accretion	115		512		—		627

General and administrative	—		—		38		38
Transaction and integration costs	—		—		8		8

Operating income (loss)	90		150		(43)		197


Equity in earnings of unconsolidated affiliates	3		32		—		35


Other income, net	6		31		11		48
Loss on debt extinguishment	—		(5)		—		(5)
Interest expense	(35)		(176)		(96)		(307)
Income (loss) before income taxes	64		32		(128)		(32)
Income tax expense	—		1		—		1
Net Income (Loss)	64		31		(128)		(33)
Less: Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	—		(236)		—		(236)
Net Income (Loss) Attributable to Clearway Energy LLC	$	64	$	267	$	(128)	$	203
Balance Sheet
Equity investments in affiliates	$	75	$	234	$	—	$	309
Capital expenditures (b)	9		179		—		188
Total Assets	$	1,933	$	12,236	$	151	$	14,320

(a) Includes eliminations.

(b) Includes accruals.


	Year ended December 31, 2023
(In millions)	Flexible Generation		Renewables & Storage		Corporate (a)		Total
Operating revenues	$	420	$	894	$	—	$	1,314
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below	154		321		(2)		473
Depreciation, amortization and accretion	129		397		—		526
Impairment losses	—		12		—		12
General and administrative	—		—		35		35
Transaction and integration costs	—		—		4		4

Operating income (loss)	137		164		(37)		264
Equity in earnings of unconsolidated affiliates	3		9		—		12


Other income, net	4		24		24		52
Loss on debt extinguishment	—		(6)		—		(6)
Interest expense	(35)		(205)		(97)		(337)
Income (loss) before income taxes	109		(14)		(110)		(15)
Income tax benefit	—		(2)		—		(2)
Net Income (Loss)	109		(12)		(110)		(13)
Less: Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	—		(162)		—		(162)
Net Income (Loss) Attributable to Clearway Energy LLC	$	109	$	150	$	(110)	$	149

(a) Includes eliminations.

Accounting for Derivative Instruments and Hedging Activities - Schedule of Offsetting of Derivatives (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Derivative [Line Items]
Derivative assets, gross	$ 156	$ 175
Derivative liabilities, gross	(360)	(371)
Gross Amounts of Recognized Assets/Liabilities	(204)	(196)
Derivative Instruments	0	0
Net Amount	(204)	(196)
Energy-related commodity contracts
Derivative [Line Items]
Derivative assets, gross	14	9
Derivative instruments, assets	0	0
Net Amount	14	9
Derivative liabilities, gross	(333)	(371)
Derivative Instruments	0	0
Net Amount	(333)	(371)
Gross Amounts of Recognized Assets/Liabilities	(319)	(362)
Derivative Instruments	0	0
Net Amount	(319)	(362)
Interest rate contracts
Derivative [Line Items]
Derivative assets, gross	142	166
Derivative instruments, assets	0	0
Net Amount	142	166
Derivative liabilities, gross	(27)
Derivative Instruments	0
Net Amount	(27)
Gross Amounts of Recognized Assets/Liabilities	115	166
Derivative Instruments	0	0
Net Amount	$ 115	$ 166

Leases - Schedule of Property, Plant, and Equipment Net (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Leases [Abstract]
Property, plant and equipment	$ 6,642	$ 6,284
Accumulated depreciation	(2,520)	(2,276)
Net property, plant and equipment	$ 4,122	$ 4,008

Audit Information	12 Months Ended
Audit Information	Dec. 31, 2025
Audit Information [Abstract]
Auditor Firm ID	238
Auditor Name	PricewaterhouseCoopers LLP
Auditor Location	Baltimore, Maryland

Nature of Business (Tables)	12 Months Ended
Nature of Business (Tables)	Dec. 31, 2025
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Company Organization Chart	The diagram below represents a summarized structure of the Company as of December 31, 2025:

Acquisitions and Dispositions

12 Months Ended

Dec. 31, 2025

Business Combination, Asset Acquisition, Transaction between Entities under Common Control, and Joint Venture Formation [Abstract]

Acquisitions and Dispositions

Acquisitions

As further described in Note 2, Summary of Significant Accounting Policies, the Company records the assets acquired and liabilities assumed at acquisition-date fair value, except in the case of acquisitions under common control by CEG, for which assets acquired and liabilities assumed are recorded at historical cost on the acquisition date, which, in certain circumstances, represent the acquired cost.

The fair value of property, plant and equipment for the Company’s third-party acquisition of Tuolumne was determined primarily based on an income method using discounted cash flows and validated using a cost approach based on the replacement cost of the assets less economic depreciation. This methodology was utilized as the forecasted cash flows incorporate specific attributes including age, useful life, equipment condition and technology. The fair value of intangible assets for power purchase agreements related to the Company’s third-party acquisitions of Tuolumne and Catalina were determined utilizing a variation of the income approach determined by discounting the replacement market price of the incremental cash flows associated with the contract to present value. Primary assumptions utilized included estimates of generation, contractual prices, operating expenses and the weighted average cost of capital reflective of a market participant. These assumptions are considered to be a Level 3 measurement as defined in ASC 820, as they utilize inputs that are not observable in the market.

Pine Forest Drop Down — On June 10, 2025, the Company, through its indirect subsidiary, Pine Forest CE Class A Owner LLC, acquired the Class A membership interests in Pine Forest TargetCo, a partnership and the indirect owner of Pine Forest, a 300 MW solar facility that is paired with a 200 MW BESS facility located in Hopkins County, Texas, from Clearway Renew for initial cash consideration of $18 million. Simultaneously, a third-party cash equity investor acquired the Class B membership interests in Pine Forest TargetCo from Clearway Renew for initial cash consideration of $36 million. Also on June 10, 2025, Clearway, Inc., through its indirect subsidiary, Pine Forest TE Class A, contributed $9 million to acquire the Class A membership interests in Pine Forest TE HoldCo LLC. On December 17, 2025, when the facility reached substantial completion, the Company paid $50 million to Clearway Renew as additional purchase price for its Class A membership interests in Pine Forest TargetCo and Clearway, Inc., through Pine Forest TE Class A, contributed an additional $38 million for its Class A membership interests in Pine Forest TE HoldCo LLC. In addition, the third-party cash equity investor in Pine Forest TargetCo contributed an additional $144 million. Pine Forest TargetCo consolidates as primary beneficiary, Pine Forest TE HoldCo LLC, a tax equity fund that directly owns the Pine Forest solar and BESS facility, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities.

Pine Forest has PPAs for the solar facility with investment-grade counterparties and a 20-year weighted average contract duration that commenced in December 2025. Pine Forest is reflected in the Company’s Renewables & Storage segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Pine Forest on a prospective basis in its financial statements. The assets and liabilities transferred to the Company relate to interests under common control and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The sum of the initial cash consideration of $18 million and the historical cost of the Company’s net liabilities assumed of $9 million was recorded as an adjustment to contributed capital. The $50 million additional purchase price was also recorded as an adjustment to contributed capital. In addition, the Company reflected the entire $18 million of the Company’s initial purchase price and $50 million of the Company’s additional purchase price, which were contributed back to the Company by CEG to pay down the acquired long-term debt, in the line item contributions from CEG, net of distributions, in the consolidated statements of members’ equity. The Company’s total capital investment in Pine Forest TargetCo was $68 million.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of June 10, 2025:


(In millions)	Pine Forest
Restricted cash	$	1
Property, plant and equipment (a)	560
Right-of-use assets, net	17
Derivative assets	6

Total assets acquired	584

Long-term debt (b)	515
Long-term lease liabilities	18
Derivative liabilities	1
Other current and non-current liabilities	54
Total liabilities assumed	588
Other comprehensive income	5
Net liabilities assumed	$	(9)

(a) Includes Construction in progress of $550 million.

Honeycomb Portfolio Drop Down — On October 15, 2025, the Company, through its indirect subsidiary, Honeycomb 1 Holdco LLC, acquired Honeycomb TargetCo, the indirect owner of the Honeycomb Portfolio, which includes four BESS facilities under construction in Beaver County and Iron County, Utah representing 320 MW of capacity, from Clearway Renew for initial cash consideration of $16 million. At substantial completion, which is expected to occur in the first half of 2026, the Company estimates it will pay an additional $62 million to Clearway Renew. Honeycomb TargetCo consolidates as primary beneficiary, Honeycomb TE HoldCo LLC, a tax equity fund that owns the Honeycomb Portfolio BESS facilities, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. The Honeycomb Portfolio has 20-year PPAs with an investment-grade utility that will commence when the underlying operating assets reach commercial operations, which is expected to occur in the first half of 2026. The Honeycomb Portfolio is reflected in the Company’s Renewables & Storage segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates the Honeycomb Portfolio on a prospective basis in its financial statements. The assets and liabilities transferred to the Company relate to interests under common control and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The sum of the Company’s initial cash consideration of $16 million and the historical cost of the Company’s net liabilities assumed of $2 million was recorded as an adjustment to contributed capital. The Company estimates that its total capital investment in Honeycomb TargetCo will be $78 million, excluding the impact of any closing adjustments noted in the purchase agreement.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of October 15, 2025:


(In millions)	Honeycomb Portfolio
Cash	$	1
Property, plant and equipment (a)	480
Right-of-use assets, net	3
Derivative assets	4
Other current and non-current assets	7

Total assets acquired	495

Long-term debt (b)	443
Long-term lease liabilities	3
Derivative liabilities	7
Other current and non-current liabilities	47
Total liabilities assumed	500
Other comprehensive loss	(3)
Net liabilities assumed	$	(2)

(a) Includes Construction in progress of $473 million.

Daggett 1 Drop Down — On April 29, 2025, the Company, through its indirect subsidiary, LV-Daggett Parent Holdco LLC, acquired Daggett 1 Class B, the indirect owner of Daggett 1, a 114 MW BESS facility located in San Bernardino County, California, from Clearway Renew for initial cash consideration of $11 million. On September 19, 2025, when the facility reached substantial completion, the Company paid $42 million to Clearway Renew as additional purchase price. Daggett 1 Class B consolidates as primary beneficiary, Daggett 1 TE Holdco LLC, a tax equity fund that owns the Daggett 1 BESS facility, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. Daggett 1 has a PPA for capacity with an investment-grade counterparty for a contract duration of 15 years that commenced in September 2025. Daggett 1 is reflected in the Company’s Renewables & Storage segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Daggett 1 on a prospective basis in its financial statements. The assets and liabilities transferred to the Company relate to interests under common control and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the initial cash consideration of $11 million and the historical cost of the Company’s net assets acquired of $1 million was recorded as an adjustment to contributed capital. The $42 million additional purchase price was also recorded as an adjustment to contributed capital. In addition, the Company reflected the entire $11 million of the Company’s initial purchase price, which was contributed back to the Company by CEG into escrow in the line item contributions from CEG, net of distributions, in the consolidated statements of members’ equity. The Company also reflected the entire $42 million of the Company’s additional purchase price, which was contributed back to the Company by CEG to pay down long-term debt, in the line item contributions from CEG, net of distributions, in the consolidated statements of members’ equity.

On October 15, 2025, the Company paid $4 million to Clearway Renew as a final purchase price adjustment, which was recorded as an adjustment to contributed capital. The Company’s total capital investment in Daggett 1 Class B was $57 million.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of April 29, 2025:


(In millions)	Daggett 1
Cash	$	1
Property, plant and equipment (a)	223

Other current and non-current assets	8

Total assets acquired	232

Long-term debt (b)	220

Derivative liabilities	6
Other current and non-current liabilities	11
Total liabilities assumed	237
Other comprehensive loss	(6)
Net assets acquired	$	1

(a) Includes Construction in progress of $221 million.

Luna Valley Drop Down — On April 29, 2025, the Company, through its indirect subsidiary, LV-Daggett Parent Holdco LLC, acquired Luna Valley Class B, the indirect owner of Luna Valley, a 200 MW solar facility located in Fresno County, California, from Clearway Renew for initial cash consideration of $18 million. On September 4, 2025, when the facility reached substantial completion, the Company paid $72 million to Clearway Renew as additional purchase price. Luna Valley Class B consolidates as primary beneficiary, Luna Valley TE Holdco LLC, a tax equity fund that owns the Luna Valley solar facility, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. Luna Valley has PPAs with investment-grade counterparties that have a 17-year weighted average contract duration that commenced in August 2025. Luna Valley is reflected in the Company’s Renewables & Storage segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Luna Valley on a prospective basis in its financial statements. The assets and liabilities transferred to the Company relate to interests under common control and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The sum of the initial cash consideration of $18 million and the historical cost of the Company’s net liabilities assumed of $7 million was recorded as an adjustment to contributed capital. The $72 million additional purchase price was also recorded as an adjustment to contributed capital. In addition, the Company reflected the entire $18 million of the Company’s initial purchase price and $72 million of the Company’s additional purchase price, which were contributed back to the Company by CEG to pay down the acquired long-term debt, in the line item contributions from CEG, net of distributions, in the consolidated statements of members’ equity.

On October 15, 2025, the Company paid $29 million to Clearway Renew as a final purchase price adjustment, which was recorded as an adjustment to contributed capital. The Company’s total capital investment in Luna Valley Class B was $119 million.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of April 29, 2025:


(In millions)	Luna Valley
Restricted cash	$	8
Property, plant and equipment (a)	346
Right-of-use assets, net (b)	16
Other current and non-current assets	22

Total assets acquired	392

Long-term debt (c)	348
Long-term lease liabilities (b)	18
Derivative liabilities	8
Other current and non-current liabilities	33
Total liabilities assumed	407
Other comprehensive loss	(8)
Net liabilities assumed	$	(7)

(a) Includes Construction in progress of $338 million.

(b) Balances primarily relate to a land lease agreement with a wholly-owned subsidiary of CEG, which expires on September 23, 2058.

Rosamond South I Drop Down — On March 20, 2025, the Company, through its indirect subsidiary, Rosamond South Investment LLC, acquired the Class A membership interests in Rosie South TargetCo, a partnership and the indirect owner of Rosamond South I, a 140 MW solar facility that is paired with a 117 MW BESS facility located in Rosamond, California, from Clearway Renew for initial cash consideration of $4 million. Simultaneously, a third-party cash equity investor acquired the Class B membership interests in Rosie South TargetCo from Clearway Renew for initial cash consideration of $10 million. On August 13, 2025, when the facility reached substantial completion, the Company paid $29 million to Clearway Renew as additional purchase price and the third-party cash equity investor contributed an additional $41 million. Rosie South TargetCo consolidates as primary beneficiary, Rosie South TE Holdco LLC, a tax equity fund that directly owns the Rosamond South I solar and BESS facility, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. Rosamond South I has PPAs with investment-grade counterparties that have a 15-year weighted average contract duration that commenced in August 2025. Rosamond South I is reflected in the Company’s Renewables & Storage segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Rosamond South I on a prospective basis in its financial statements. The assets and liabilities transferred to the Company relate to interests under common control and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The sum of the initial cash consideration of $4 million and the historical cost of the Company’s net liabilities assumed of $3 million was recorded as an adjustment to contributed capital. The $29 million additional purchase price was also recorded as an adjustment to contributed capital. In addition, the Company reflected the entire $4 million of the Company’s initial purchase price and $29 million of the Company’s additional purchase price, which were contributed back to the Company by CEG to pay down the acquired long-term debt, in the line item contributions from CEG, net of distributions, in the consolidated statements of members’ equity. The Company’s total capital investment in Rosie South TargetCo was $33 million.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of March 20, 2025:


(In millions)	Rosamond South I

Property, plant and equipment (a)	$	507
Right-of-use assets, net (b)	17

Other current and non-current assets	11

Total assets acquired	535

Long-term debt (c)	468
Long-term lease liabilities (b)	19
Derivative liabilities	4
Other current and non-current liabilities	51
Total liabilities assumed	542
Other comprehensive loss	(4)
Net liabilities assumed	$	(3)

(a) Includes Construction in progress of $495 million.

(b) Balances primarily relate to a land lease agreement with a wholly-owned subsidiary of CEG, which expires on September 30, 2058.

Catalina Solar Acquisition — On July 16, 2025, the Company, through its indirect subsidiary, Catalina Solar Investment LLC, acquired Catalina Solar Lessee Holdco LLC, which leases and operates Catalina, a 109 MW solar facility located in Kern County, California, from a third-party for approximately $127 million, which excludes $1 million in transaction expenses incurred in connection with the acquisition. Catalina reached commercial operations in 2013 and has a PPA with an investment-grade utility through 2038. Catalina is reflected in the Renewables & Storage segment and the acquisition was funded with existing sources of liquidity. After factoring in cash reserves acquired and transaction expenses, the Company’s net capital investment in Catalina was $128 million. The acquisition was determined to be an asset acquisition and the purchase price, including transaction expenses, was allocated to the fair value of the assets acquired and liabilities assumed on the acquisition date as follows:


(In millions)	Catalina
Cash	$	15
Intangible asset for power purchase agreement	175
Right-of-use assets	107
Other current and non-current assets	6

Total assets acquired	303

Long-term lease liabilities	173
Other current and non-current liabilities	2
Total liabilities assumed	175
Net assets acquired	$	128

Dan’s Mountain Drop Down — On November 18, 2024, the Company, through its indirect subsidiary, Dan’s Mountain Parent Holdco LLC, acquired the Class A membership interests in Dan’s Mountain TargetCo, a partnership and the indirect owner of Dan’s Mountain, a 55 MW wind facility located in Allegany County, Maryland, from Clearway Renew for initial cash consideration of $7 million. On May 21, 2025, when the facility reached substantial completion, the Company paid $36 million to Clearway Renew as additional purchase price. Also on May 21, 2025, a third-party cash equity investor contributed $45 million to acquire the Class B membership interests in Dan’s Mountain TargetCo from Clearway Renew. Dan’s Mountain TargetCo consolidates as primary beneficiary, Dan’s Mountain Tax Credit Holdco LLC, a tax equity fund that owns the Dan’s Mountain wind facility. Dan’s Mountain has a 12-year PPA with an investment-grade utility that commenced in May 2025. Dan’s Mountain is reflected in the Company’s Renewables & Storage segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Dan’s Mountain on a prospective basis in its financial statements. The assets and liabilities transferred to the Company relate to interests under common control and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The sum of the Company’s initial cash consideration of $7 million and the historical cost of the Company’s net liabilities assumed of $2 million, less Clearway Renew’s investment of $1 million in Dan’s Mountain TargetCo, was recorded as an adjustment to contributed capital. The $36 million additional purchase price was also recorded as an adjustment to contributed capital. In addition, the Company reflected the entire $7 million purchase price, which was contributed back to the Company by CEG to pay down the acquired long-term debt, in the line item contributions from CEG, net of distributions, in the consolidated statements of members’ equity. The Company also reflected the entire $36 million of the Company’s additional purchase price, which was contributed back to the Company by CEG to pay down the acquired long-term debt, in the line item contributions from CEG, net of distributions, in the consolidated statements of members’ equity. The Company’s total capital investment in Dan’s Mountain TargetCo was $43 million.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of November 18, 2024:


(In millions)	Dan’s Mountain

Property, plant and equipment (a)	$	152
Right-of-use assets	3



Total assets acquired	155

Long-term debt (b)	125
Long-term lease liabilities	3
Other current and non-current liabilities	29
Total liabilities assumed	157
Net liabilities assumed	$	(2)

(a) Includes Construction in progress of $150 million.

Tuolumne Wind Acquisition — On April 29, 2025, the Company, through its indirect subsidiary, Washington Wind LLC, acquired Tuolumne, a 137 MW wind facility located in Klickitat County, Washington, from an investment-grade regulated entity for approximately $210 million, which excludes $1 million in transaction expenses incurred in connection with the acquisition. Tuolumne reached commercial operations in 2009. In connection with the acquisition, the Company entered into a 15-year PPA with an investment-grade regulated entity that commenced in April 2025. Tuolumne is reflected in the Company’s Renewables & Storage segment and the acquisition was funded with borrowings under the new financing agreement that was entered into in connection with the acquisition, as further described in Note 10, Long-term Debt, as well as existing sources of liquidity. After factoring in transaction expenses and the new financing, the Company’s net capital investment in Tuolumne was $59 million. The acquisition was determined to be an asset acquisition and the purchase price, including transaction expenses, was allocated to the fair value of the assets acquired and liabilities assumed on the acquisition date as follows:


(In millions)	Tuolumne
Property, plant and equipment	$	37
Intangible asset for power purchase agreement	176
Right-of-use assets	5
Other current and non-current assets	1

Total assets acquired	219

Long-term lease liabilities	4
Other current and non-current liabilities	4
Total liabilities assumed	8
Net assets acquired	$	211

Rosamond Central BESS Drop Down — On December 1, 2023, the Rosamond Central solar facility acquired a 147 MW co-located BESS facility from Clearway Renew for initial cash consideration of $70 million, $16 million of which was funded by the Company, with the remaining $54 million funded through contributions from the third-party cash equity investor in Rosie TargetCo LLC and the tax equity investor in Rosie TE HoldCo LLC. On June 13, 2024, when the Rosamond Central BESS facility reached substantial completion, the Company paid $279 million to Clearway Renew as additional purchase price to complete its acquisition of the facility. The additional purchase price consisted of $64 million funded by the Company and $215 million funded through contributions from the third-party cash equity and tax equity investors. In order to facilitate and fund the construction of the BESS facility, Rosie Class B LLC, the indirect owner of the Rosamond Central solar facility, utilizing the proceeds from borrowings received under the refinanced debt facility, issued a loan to Clearway Renew, as further described in Note 10, Long-term Debt, and also made equity contributions to Rosie BESS Devco LLC, or Rosie Central BESS, which were accounted for as investments under the equity method of accounting, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. The BESS facility has a 15-year PPA for capacity with an investment-grade utility that commenced in July 2024. The Rosamond Central BESS operations are reflected in the Company’s Renewables & Storage segment and the Company’s portion of the purchase price was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates the Rosamond Central BESS net assets on a prospective basis in its financial statements. The assets and liabilities transferred to the Company relate to interests under common control and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the historical cost of the Company’s net assets acquired of $266 million and the Company’s initial cash consideration of $70 million was recorded as an adjustment to contributed capital. The $279 million additional purchase price was also recorded as an adjustment to contributed capital.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of December 1, 2023:


(In millions)	Rosamond Central BESS
Property, plant and equipment (a)	$	275

Total assets acquired	275

Other current and non-current liabilities	9
Total liabilities assumed	9
Net assets acquired	$	266

(a) Includes Construction in progress of $272 million.

Victory Pass and Arica Drop Down — On October 31, 2023, the Company, through its indirect subsidiary, VP-Arica Parent Holdco LLC, acquired the Class A membership interests in VP-Arica TargetCo LLC, a partnership and the indirect owner of Victory Pass, a 200 MW solar facility that is paired with a 50 MW BESS facility, and Arica, a 263 MW solar facility that is paired with a 136 MW BESS facility, both located in Riverside, California, from Clearway Renew for initial cash consideration of $46 million. Simultaneously, a third-party cash equity investor acquired the Class B membership interests in VP-Arica TargetCo LLC from Clearway Renew for initial cash consideration of $87 million. On May 1, 2024, when the facilities reached substantial completion, the Company paid $165 million to Clearway Renew as additional purchase price and the third-party cash equity investor contributed an additional $347 million. VP-Arica TargetCo LLC consolidates as primary beneficiary, VP-Arica TE Holdco LLC, a tax equity fund that owns the Victory Pass and Arica solar and BESS facilities. Victory Pass and Arica each have PPAs with investment-grade counterparties that have a 15-year and 14-year weighted average contract duration, respectively, that commenced between March 2024 and April 2024. The Victory Pass and Arica operations are reflected in the Company’s Renewables & Storage segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Victory Pass and Arica on a prospective basis in its financial statements. The assets and liabilities transferred to the Company relate to interests under common control and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The sum of the Company’s initial cash consideration of $46 million and the historical cost of the Company’s net liabilities assumed of $1 million was recorded as an adjustment to contributed capital. The $165 million additional purchase price was also recorded as an adjustment to contributed capital. In addition, the Company reflected the entire $46 million of the Company’s initial purchase price, which was contributed back to the Company by CEG to pay down the acquired long-term debt, in the line item distributions to CEG, net of contributions, in the consolidated statements of members’ equity. The Company also reflected the entire $165 million of the Company’s additional purchase price, which was contributed back to the Company by CEG to pay down long-term debt, in the line item contributions to CEG, net of distributions, in the consolidated statements of members’ equity.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of October 31, 2023:


(In millions)	Victory Pass and Arica
Cash	$	1
Property, plant and equipment (a)	937
Right-of-use assets, net	4
Derivative assets	1
Other non-current assets	6

Total assets acquired	949

Long-term debt (b)	864
Long-term lease liabilities	4
Other current and non-current liabilities	82
Total liabilities assumed	950
Net liabilities assumed	$	(1)

(a) Includes Construction in progress of $893 million.

Cedar Creek Drop Down — On April 16, 2024, the Company, through its indirect subsidiary, Cedar Creek Wind Holdco LLC, acquired Cedar Creek Holdco LLC, the indirect owner of Cedar Creek, a 160 MW wind facility that is located in Bingham County, Idaho, from Clearway Renew for cash consideration of $117 million. Cedar Creek Holdco LLC consolidates as primary beneficiary, Cedar Creek TE Holdco LLC, a tax equity fund that owns the Cedar Creek wind facility. Cedar Creek has a 25-year PPA with an investment-grade utility that commenced in March 2024. The Cedar Creek operations are reflected in the Company’s Renewables & Storage segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Cedar Creek on a prospective basis in its financial statements. The assets and liabilities transferred to the Company relate to interests under common control and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the Company’s cash paid of $117 million and the historical cost of the Company’s net assets acquired of $17 million was recorded as an adjustment to contributed capital. In addition, the Company reflected the entire $117 million purchase price, which was contributed back to the Company by CEG to pay down the acquired long-term debt, in the line item contributions from CEG, net of distributions, in the consolidated statements of members’ equity.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of April 16, 2024:


(In millions)	Cedar Creek
Restricted cash	$	1
Property, plant and equipment	311
Right-of-use assets, net	6
Derivative assets	14
Other current and non-current assets	14

Total assets acquired	346

Long-term debt (a)	309
Long-term lease liabilities	7
Other current and non-current liabilities	13
Total liabilities assumed	329
Net assets acquired	$	17

Texas Solar Nova 2 Drop Down — On March 15, 2024, the Company, through its indirect subsidiary, TSN1 TE Holdco LLC, acquired Texas Solar Nova 2, a 200 MW solar facility that is located in Kent County, Texas, from Clearway Renew for cash consideration of $112 million, of which $17 million was funded by the Company, with the remaining $95 million funded through a contribution from the third-party cash equity investor in Lighthouse Renewable Holdco 2 LLC, a partnership. Lighthouse Renewable Holdco 2 LLC indirectly consolidates as primary beneficiary, TSN1 TE Holdco LLC, a tax equity fund that owns Texas Solar Nova 1 and Texas Solar Nova 2. Texas Solar Nova 2 has an 18-year PPA with an investment-grade counterparty that commenced in February 2024. The Texas Solar Nova 2 operations are reflected in the Company’s Renewables & Storage segment and the Company’s portion of the purchase price was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Texas Solar Nova 2 on a prospective basis in its financial statements. The assets and liabilities transferred to the Company relate to interests under common control and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the Company’s cash paid of $112 million and the historical cost of the Company’s net assets acquired of $72 million was recorded as an adjustment to contributed capital. In addition, the Company reflected $9 million of the Company’s purchase price, which was contributed back to the Company by CEG to pay down the acquired long-term debt, in the line item contributions from CEG, net of distributions, in the consolidated statements of members’ equity.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of March 15, 2024:


(In millions)	Texas Solar Nova 2
Restricted cash	$	1
Property, plant and equipment	280
Right-of-use assets, net	21
Derivative assets	6
Other current and non-current assets	4

Total assets acquired	312

Long-term debt (a)	194
Long-term lease liabilities	19
Other current and non-current liabilities	27
Total liabilities assumed	240
Net assets acquired	$	72

Dispositions

Mt. Storm Sale to Clearway Renew — On October 2, 2025, the Company, through its indirect subsidiary, WV Wind Holdco LLC, sold 100% of its membership interests in Mount Storm Wind LLC, which owns Mt. Storm, a 264 MW wind facility located in Grant County, West Virginia, to Clearway Renew for $152 million in cash consideration in order for Clearway Renew to repower the facility. The repowering of the facility is expected to increase the facility’s capacity to 335 MW. Mechanical completion of the first phase of the repowering is expected to occur in the second half of 2026 with the second phase of the repowering expected to occur in the second half of 2027. Also on October 2, 2025, the Company, through its indirect subsidiary, WV Wind Holdco LLC, entered into an agreement with Clearway Renew to acquire the Class B membership interests in the tax equity fund that, upon mechanical completion of the first phase of the repowering of the facility, will own Mt. Storm, for $336 million in cash consideration. The consummation of the transaction is subject to customary closing conditions and certain third-party approvals and is expected to occur in the second half of 2026. Upon achieving repowering commercial operations, which is expected to occur in the second half of 2026, the facility will sell power to Microsoft under a 20-year PPA. The membership interests sold by the Company relate to interests under common control, and thus, the sale was accounted for as a transfer of assets under common control, with the difference between the cash received of $152 million and the net assets transferred of $51 million recorded as an adjustment to contributed capital.

The following is a summary of assets and liabilities transferred in connection with the disposition as of October 2, 2025:


(In millions)	Mt. Storm
Property, plant and equipment	$	54


Other current and non-current assets	6

Total assets transferred	60


Other current and non-current liabilities	9
Total liabilities transferred	9
Net assets transferred	$	51

Members' Equity - Narrative (Details) - USD ($)				1 Months Ended	12 Months Ended
Members' Equity - Narrative (Details) - USD ($)	Feb. 16, 2026	Dec. 17, 2025	Jun. 10, 2025	Jan. 31, 2026	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Aug. 06, 2025
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Pro-rata distributions to CEG		$ 28,000,000	$ 16,000,000		$ 358,000,000	$ 334,000,000	$ 311,000,000
Clearway Energy, Inc.
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Pro-rata distributions to CEG		16,000,000	9,000,000
CEG
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Pro-rata distributions to CEG		$ 12,000,000	$ 7,000,000
Common Class C \| Subsequent Event
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Quarterly dividend, declared (in usd per share)	$ 0.4602
Common Class C \| Dividend Reinvestment and Direct Stock Purchase Plan
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Accrued professional fees					$ 1,000,000
Reserved for issuance up to an aggregate (in shares)								3,300,000
Proceeds from issuance of stock					793,202
Proceeds from issuance of stock					$ 25,000,000
Remain stock available for issuance (in share)					2,506,798
Common Class C \| Dividend Reinvestment and Direct Stock Purchase Plan \| Subsequent Event
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Stock issued during period, issued for services (in shares)				1,445,244
Accrued professional fees				$ 1,000,000
Reserved for issuance up to an aggregate (in shares)				1,061,554
Proceeds from issuance of stock				$ 50,000,000
Common Class C \| Dividend Reinvestment and Direct Stock Purchase Plan \| Other Registed Stockholders And New Investors
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Dividend reinvestment plan, initial investment								$ 150,000
Common Class C \| Dividend Reinvestment and Direct Stock Purchase Plan \| Minimum \| Existing Investor
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Dividend reinvestment plan, initial investment								50
Common Class C \| Dividend Reinvestment and Direct Stock Purchase Plan \| Minimum \| New Investor
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Dividend reinvestment plan, initial investment								250
Common Class C \| Dividend Reinvestment and Direct Stock Purchase Plan \| Maximum \| Existing Investor
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Dividend reinvestment plan, initial investment								150,000
Common Class C \| Dividend Reinvestment and Direct Stock Purchase Plan \| Maximum \| New Investor
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Dividend reinvestment plan, initial investment								150,000
Common Class A \| Subsequent Event
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Quarterly dividend, declared (in usd per share)	0.4602
Common Class B \| Subsequent Event
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Quarterly dividend, declared (in usd per share)	0.4602
Common Class D \| Subsequent Event
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Quarterly dividend, declared (in usd per share)	$ 0.4602
Capital Unit, Class C \| Dividend Reinvestment and Direct Stock Purchase Plan
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Stock issued during period, issued for services (in shares)					793,202
Capital Unit, Class C \| Dividend Reinvestment and Direct Stock Purchase Plan \| Subsequent Event
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Proceeds from issuance of stock				1,445,244
ATM Program
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Aggregate sales price								$ 100,000,000
Available for issuance under ATM program					$ 75,000,000
ATM Program \| Common Class C
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Sale of stock, number of shares issued in transaction (in shares)					787,980
Sale of stock, consideration received per transaction					$ 25,000,000
Accrued professional fees					$ 1,000,000
ATM Program \| Capital Unit, Class C
Distribution Made to Limited Liability Company (LLC) Member [Line Items]
Stock issued during period, issued for services (in shares)					787,980

Related Party Transactions	12 Months Ended
Related Party Transactions	Dec. 31, 2025
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions In addition to the transactions and relationships described elsewhere in the notes to the consolidated financial statements, certain subsidiaries of CEG provide services to the Company and its operating subsidiaries. Amounts due to CEG subsidiaries are recorded as accounts payable — affiliates and amounts due to the Company from CEG subsidiaries are recorded as accounts receivable — affiliates in the Company’s consolidated balance sheets. The disclosures below summarize the Company’s material related party transactions with CEG and its subsidiaries that are included in the Company’s operating costs. Master Development Services Agreement with Clearway Renew On December 22, 2025, the Company entered into a master development services agreement with Clearway Renew under which Clearway Renew will provide pre-construction development, construction management and asset management services in connection with future approved repowerings of the Company’s facilities. The Company did not incur any expenses under this agreement for the year ended December 31, 2025. Loan with Clearway Energy Finance Inc. On December 17, 2025, in connection with the Pine Forest solar and BESS facility reaching substantial completion, as further discussed in Note 3, Acquisitions and Dispositions, the Company issued a loan to Clearway Energy Finance Inc., a subsidiary of Clearway, Inc., in the amount of $22 million in order to partially fund Pine Forest TE Class A’s additional contribution. The loan bears interest at a fixed rate of 6% and matures on December 17, 2045. As of December 31, 2025, the full $22 million remained outstanding, with the significant majority included in other non-current assets on the Company’s consolidated balance sheet. Goat Mountain Development Services Agreement with Clearway Renew On July 23, 2025, the Company entered into a development services agreement with Clearway Renew under which Clearway Renew will provide pre-construction development, construction management and asset management services in connection with the repowering of the Goat Mountain wind facility, which is located in Sterling City, Texas. Contingent upon achieving repowering commercial operations in 2027, the 306 MW facility will sell power to an investment-grade counterparty under a new 15-year PPA. In connection with the agreement, on December 12, 2025, the Company paid Clearway Renew $27 million, of which $25 million is related to the future delivery of equipment and is included in other non-current assets on the Company’s consolidated balance sheet, and $2 million is related to capital expenditures. O&M Services Agreements by and between the Company and Clearway Renewable Operation & Maintenance LLC Various wholly-owned subsidiaries of the Company in the Renewables & Storage segment are party to services agreements with Clearway Renewable Operation & Maintenance LLC, or RENOM, a wholly-owned subsidiary of CEG, which provides operation and maintenance, or O&M, services to these subsidiaries. The Company incurred total expenses for these services of $82 million for each of the years ended December 31, 2025 and 2024, and $73 million for the year ended December 31, 2023, included in cost of operations in the consolidated statements of operations. There was a balance of $8 million and $12 million due to RENOM as of December 31, 2025 and 2024, respectively. Administrative Services Agreements by and between the Company and CEG Various wholly-owned subsidiaries of the Company are parties to services agreements with Clearway Asset Services LLC and Clearway Solar Asset Management LLC, two wholly-owned subsidiaries of CEG, which provide various administrative services to the Company’s subsidiaries. The Company incurred expenses under these agreements of $26 million, $22 million and $20 million for the years ended December 31, 2025, 2024 and 2023, respectively, included in cost of operations in the consolidated statements of operations. There was a balance of $3 million due to CEG as of December 31, 2025 and 2024. CEG Master Services Agreement The Company, along with Clearway, Inc. and certain of its subsidiaries, is a party to the CEG Master Services Agreement, pursuant to which CEG and certain of its affiliates or third-party service providers provide certain services to the Company, including operational and administrative services, which include human resources, information systems, cybersecurity, external affairs, accounting, procurement and risk management services, and, effective on January 1, 2025, accounting, internal audit, tax, legal and treasury services, in exchange for the payment of fees in respect of such services. Until January 1, 2025, the Company provided certain services to CEG under a separate Master Services Agreement, including accounting, internal audit, tax and treasury services, in exchange for the payment of fees in respect of such services. Effective January 1, 2025, the Company directly bears all labor costs for certain employees of CEG who perform work on behalf of the Company. The Company incurred net expenses under the CEG Master Services Agreement of $24 million, $6 million and $5 million for the years ended December 31, 2025, 2024 and 2023, respectively, included in general and administrative in the consolidated statements of operations. There was a balance of zero and $5 million due to CEG as of December 31, 2025 and 2024, respectively.

- Definition

The entire disclosure for related party transactions. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 850
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483326/850-10-50-1

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 946
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480990/946-20-50-2

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 946
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 5
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480990/946-20-50-5

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 946
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 6
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480990/946-20-50-6

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 946
-SubTopic 235
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147477968/946-235-50-2

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 946
-SubTopic 235
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (e)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147477968/946-235-50-2

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 946
-SubTopic 220
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.6-07(2)(g)(3))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479134/946-220-S99-1

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 946
-SubTopic 220
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.6-07(2)(c))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479134/946-220-S99-1

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 946
-SubTopic 220
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.6-07(2)(e))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479134/946-220-S99-1

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 850
-Name Accounting Standards Codification
-Publisher FASB
-URI https://asc.fasb.org/850/tableOfContent

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 850
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 6
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483326/850-10-50-6

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 850
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483326/850-10-50-1

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Topic 850
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483326/850-10-50-1

+ Details

Members' Equity (Tables)

12 Months Ended

Dec. 31, 2025

Members' Equity [Abstract]

Schedule of Dividends Paid

The following tables list the distributions paid on the Company’s Class A, Class B, Class C and Class D units during the years ended December 31, 2025, 2024 and 2023:


	Fourth Quarter 2025		Third Quarter 2025		Second Quarter 2025		First Quarter 2025
Distributions per Class A and Class B units	$	0.4528	$	0.4456	$	0.4384	$	0.4312
Distributions per Class C and Class D units	0.4528		0.4456		0.4384		0.4312


	Fourth Quarter 2024		Third Quarter 2024		Second Quarter 2024		First Quarter 2024
Distributions per Class A and Class B units	$	0.4240	$	0.4171	$	0.4102	$	0.4033
Distributions per Class C and Class D units	0.4240		0.4171		0.4102		0.4033


	Fourth Quarter 2023		Third Quarter 2023		Second Quarter 2023		First Quarter 2023
Distributions per Class A and Class B units	$	0.3964	$	0.3891	$	0.3818	$	0.3745
Distributions per Class C and Class D units	0.3964		0.3891		0.3818		0.3745

Acquisitions and Dispositions - Schedule of Assets and Liabilities Transferred with Disposition (Details) - WV Wind HoldCo LLC - Disposed of by Sale - Mt. Storm Sale to Clearway Renew $ in Millions	Oct. 02, 2025 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Property, plant and equipment	$ 54
Other current and non-current assets	6
Total assets transferred	60
Other current and non-current liabilities	9
Total liabilities transferred	9
Net assets transferred	$ 51

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

12 Months Ended

Dec. 31, 2025

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Equity Method Investments

The following table reflects the Company’s equity investments in unconsolidated affiliates as of December 31, 2025:


Name	Economic Interest	Investment Balance (a)
		(In millions)
Avenal	50%	$	12
Desert Sunlight	25%	212
Elkhorn Ridge	66.7%	(3)
GenConn (b)	50%	72
San Juan Mesa	75%	(2)
		$	291

(a) The Company’s maximum exposure to loss is limited to its investment balances.

(b) GenConn is a VIE.

The following tables present summarized financial information for the Company’s equity method investments:


	Year Ended December 31,
	2025		2024		2023
Income Statement Data:	(In millions)




Desert Sunlight
Operating revenues	$	205	$	206	$	202
Operating income	149		146		144
Net income	118		113		108












Other (a)
Operating revenues	96		95		94
Operating income	31		25		23
Net income	22		16		13
			As of December 31,
			2025		2024
Balance Sheet Data:			(In millions)





Desert Sunlight
Current assets			$	77	$	81
Non-current assets			1,025		1,086
Current liabilities			66		63
Non-current liabilities			653		726

















Other (a)
Current assets			72		63
Non-current assets			358		391
Current liabilities			33		27
Non-current liabilities			208		225

(a) Includes Avenal, Elkhorn Ridge, GenConn and San Juan Mesa.

Schedule of Variable Interest Entities


(In millions)	December 31, 2025		December 31, 2024
Other current and non-current assets	$	1,031	$	755
Property, plant and equipment	7,894		5,985
Total assets	$	8,925	$	6,740
Total liabilities	$	2,594	$	1,858

- Definition

Tabular disclosure of the significant judgments and assumptions made in determining whether a variable interest (as defined) held by the entity requires the variable interest entity (VIE) (as defined) to be consolidated and (or) disclose information about its involvement with the VIE, individually or in aggregate (as applicable); the nature of restrictions, if any, on the consolidated VIE's assets and on the settlement of its liabilities reported by an entity in its statement of financial position, including the carrying amounts of such assets and liabilities; the nature of, and changes in, the risks associated with involvement in the VIE; how involvement with the VIE affects the entity's financial position, financial performance, and cash flows; the lack of recourse if creditors (or beneficial interest holders) of the consolidated VIE have no recourse to the general credit of the primary beneficiary (if applicable); the terms of arrangements, giving consideration to both explicit arrangements and implicit variable interests, if any, that could require the entity to provide financial support to the VIE, including events or circumstances that could expose the entity to a loss; the methodology used by the entity for determining whether or not it is the primary beneficiary of the variable interest entity; the significant factors considered and judgments made in determining that the power to direct the activities of a VIE that most significantly impact the VIE's economic performance are shared (as defined); the carrying amounts and classification of assets and liabilities of the VIE included in the statement of financial position; the entity's maximum exposure to loss, if any, as a result of its involvement with the VIE, including how the maximum exposure is determined and significant sources of the entity's exposure to the VIE; a comparison of the carrying amounts of the assets and liabilities and the entity's maximum exposure to loss; information about any liquidity arrangements, guarantees, and (or) other commitments by third parties that may affect the fair value or risk of the entity's variable interest in the VIE; whether or not the entity has provided financial support or other support (explicitly or implicitly) to the VIE that it was not previously contractually required to provide or whether the entity intends to provide that support, including the type and amount of the support and the primary reasons for providing the support; and supplemental information the entity determines necessary to provide.

+ References + Details

Accounting for Derivative Instruments and Hedging Activities

12 Months Ended

Dec. 31, 2025

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/OCL, 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 the Company’s energy-related commodity contracts and interest rate swaps.

Interest Rate Swaps

The Company enters into interest rate swap agreements in order to hedge the variability of expected future cash interest payments that may arise in connection with its non-recourse debt or a potential refinancing of its Senior Notes. As of December 31, 2025, the Company had interest rate derivative instruments extending through 2033, a portion of which were designated as cash flow hedges. Under the interest rate swap agreements, the Company pays a fixed rate and the counterparties to the agreements pay a variable interest rate.

Energy-Related Commodity Contracts

As of December 31, 2025, the Company had energy-related derivative instruments extending through 2033. At December 31, 2025, these contracts were not designated as cash flow or fair value hedges.

Volumetric Underlying Derivative Transactions

The following table summarizes the net notional volume buy/(sell) of the Company’s open derivative transactions broken out by commodity:


		Total Volume
		December 31, 2025		December 31, 2024
Commodity	Units	(In millions)
Power	MWh	(29)		(25)
Natural Gas	MMBtu	5		11
Interest	Dollars	$	4,080	$	1,769

Fair Value of Derivative Instruments

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


	Fair Value
	Derivative Assets				Derivative Liabilities
	December 31, 2025		December 31, 2024		December 31, 2025		December 31, 2024
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current	$	2	$	5	$	6	$	—
Interest rate contracts long-term	29		22		21		—
Total Derivatives Designated as Cash Flow Hedges	$	31	$	27	$	27	$	—
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current	$	17	$	30	$	—	$	—
Interest rate contracts long-term	94		109		—		—
Energy-related commodity contracts current	10		4		46		56
Energy-related commodity contracts long-term	4		5		287		315
Total Derivatives Not Designated as Cash Flow Hedges	$	125	$	148	$	333	$	371
Total Derivatives	$	156	$	175	$	360	$	371

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 level. As of December 31, 2025 and 2024, the amount of outstanding collateral paid or received was immaterial. The following tables summarize the offsetting of derivatives by counterparty:



	Gross Amounts Not Offset in the Statement of Financial Position
As of December 31, 2025	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Net Amount
Energy-related commodity contracts	(In millions)
Derivative assets	$	14	$	—	$	14
Derivative liabilities	(333)		—		(333)
Total energy-related commodity contracts	$	(319)	$	—	$	(319)
Interest rate contracts
Derivative assets	$	142	$	—	$	142
Derivative liabilities	(27)		—		(27)
Total interest rate contracts	$	115	$	—	$	115
Total derivative instruments	$	(204)	$	—	$	(204)


	Gross Amounts Not Offset in the Statement of Financial Position
As of December 31, 2024	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Net Amount
Energy-related commodity contracts	(In millions)
Derivative assets	$	9	$	—	$	9
Derivative liabilities	(371)		—		(371)
Total energy-related commodity contracts	$	(362)	$	—	$	(362)
Interest rate contracts
Derivative assets	$	166	$	—	$	166

Total interest rate contracts	$	166	$	—	$	166
Total derivative instruments	$	(196)	$	—	$	(196)

Accumulated Other Comprehensive Income (Loss)

The following table summarizes the effects on the Company’s accumulated OCI (OCL) balance attributable to interest rate swaps designated as cash flow hedge derivatives:


	Year ended December 31,
	2025		2024		2023
	(In millions)
Accumulated OCI beginning balance	$	15	$	20	$	27

Rosamond South I Drop Down (a)	(4)		—		—
Daggett 1 Drop Down	(6)		—		—
Luna Valley Drop Down	(8)		—		—
Pine Forest Drop Down	5		—		—
Honeycomb Portfolio Drop Down	(3)		—		—
Reclassified from accumulated OCI to income due to realization of previously deferred amounts	(3)		(1)		(5)
Mark-to-market of cash flow hedge accounting contracts	(2)		(4)		(2)
Accumulated (OCL) OCI ending balance	$	(6)	$	15	$	20
Accumulated OCI attributable to noncontrolling interests	4		8		5
Accumulated (OCL) OCI attributable to Clearway Energy LLC	$	(10)	$	7	$	15
Losses expected to be realized from OCL during the next 12 months	$	(6)

(a) Represents $2 million attributable to the Company and $2 million attributable to noncontrolling interests.

Amounts reclassified from accumulated OCI/OCL into income are recorded to interest expense.

Impact of Derivative Instruments on the Consolidated Statements of Operations

Mark-to-market gains/(losses) related to the Company’s derivatives are recorded in the consolidated statements of operations as follows:


	Year ended December 31,
	2025		2024		2023
	(In millions)
Interest Rate Contracts (Interest expense)	$	(31)	$	29	$	(17)
Energy-Related Commodity Contracts (Mark-to-market for economic hedging activities included in Total operating revenues) (a)	(20)		(32)		23
Energy-Related Commodity Contracts (Mark-to-market for economic hedging activities included in Cost of operations) (b)	1		(2)		2

(b) Relates to backbone transportation service energy-related commodity contracts at El Segundo and Walnut Creek.

See Note 6, Fair Value of Financial Instruments, for a discussion regarding concentration of credit risk.

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

+ References

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+ Details

Fair Value of Financial Instruments - Schedule of Fair Value, Assets and Liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	$ 156	$ 175
Derivative Liabilities	360	371
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	(352)	(317)
Settlements	83	(2)
Total losses for the period included in earnings	(44)	(33)
Ending balance	(313)	(352)	$ (317)
Change in unrealized losses included in earnings for derivatives and other financial instruments held as of December 31,	$ (44)	$ (33)
Fair Value, Net Derivative Asset (Liability), Recurring Basis, Unobservable Input Reconciliation, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Derivative instruments	Derivative instruments
Call Option \| El Segundo, Marsh Landing and Walnut Creek Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-Term Debt, Fair Value	$ 330	$ 366
Short-Term Debt, Fair Value	3	5
Energy-related commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	14	9
Derivative Liabilities	333	371
Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	142	166
Derivative Liabilities	27
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Change in unrealized losses included in earnings for derivatives and other financial instruments held as of December 31,	(31)	29	$ (17)
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	143	166
Derivative Liabilities	27	0
Level 2 \| Energy-related commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	1	0
Derivative Liabilities	0	0
Level 2 \| Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	142	166
Derivative Liabilities	27	0
Level 2 \| Other Financial Instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	20	19
Derivative Liabilities	333	371
Level 3 \| Energy-related commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	13	9
Derivative Liabilities	333	371
Level 3 \| Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0
Derivative Liabilities	0	0
Level 3 \| Other Financial Instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	$ 7	$ 10

Summary of Significant Accounting Policies - Schedule of Supplemental Cash Flow Information (Details) - Drop Down - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Summary of Significant Accounting Policies [Line Items]
Cash paid to acquire Drop Down Assets	$ (329)	$ (680)	$ (173)
Cash acquired from the acquisition of Drop Down Assets	11	2	128
Acquisition of Drop Down Assets, net of cash acquired	$ (318)	$ (678)	$ (45)

Long-term Debt - Narrative (Details) $ in Millions																												1 Months Ended	3 Months Ended		4 Months Ended	5 Months Ended	12 Months Ended
Long-term Debt - Narrative (Details) $ in Millions	Feb. 05, 2026 USD ($)	Jan. 13, 2026 USD ($)	Dec. 31, 2025 USD ($)	Dec. 17, 2025 USD ($)	Oct. 15, 2025 USD ($)	Sep. 19, 2025 USD ($)	Sep. 04, 2025 USD ($)	Aug. 13, 2025 USD ($)	Jun. 10, 2025 USD ($)	May 21, 2025 USD ($)	Apr. 29, 2025 USD ($)	Apr. 09, 2025 USD ($)	Mar. 20, 2025 USD ($)	Dec. 27, 2024 USD ($)	Nov. 18, 2024 USD ($)	Oct. 23, 2024 USD ($)	Jul. 25, 2024 USD ($) option	Jun. 13, 2024 USD ($)	Jun. 11, 2024 USD ($)	May 01, 2024 USD ($)	Apr. 16, 2024 USD ($)	Mar. 15, 2024 USD ($)	Dec. 28, 2023 USD ($)	Dec. 12, 2023 USD ($)	Dec. 01, 2023 USD ($)	Oct. 31, 2023 USD ($)	Jun. 30, 2023 USD ($)	Jan. 31, 2026 USD ($)	Dec. 31, 2025 USD ($)	Dec. 31, 2025 USD ($)	Dec. 31, 2025 USD ($)	Dec. 31, 2025 USD ($)	Dec. 31, 2025 USD ($)	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)
Debt Instrument [Line Items]
Total debt			$ 8,680																										$ 8,680	$ 8,680	$ 8,680	$ 8,680	$ 8,680	$ 7,235
Proceeds from the revolving credit facility																																	701	0	$ 0
Contributions from noncontrolling interests, net of distributions																																	1,043	1,319	1,120
Restricted cash			587																										587	587	587	587	587	401
Contributions from CEG																																	49	0	0
Net debt issuance costs			70																										70	70	70	70	70	57
Capital expenditures			196																										196	196	196	196	196	188
Cash Distribution
Debt Instrument [Line Items]
Restricted cash			257																										257	257	257	257	257	78
Cash Distribution \| Subsequent Event
Debt Instrument [Line Items]
Restricted cash																												$ 51
Deriva Solar Portfolio \| Subsequent Event
Debt Instrument [Line Items]
Maturity term	364 days
Pine Forest Drop Down
Debt Instrument [Line Items]
Unamortized debt issuance costs									$ 6
Payments for other fees				$ 15
Pine Forest Drop Down \| Cash Equity Investor
Debt Instrument [Line Items]
Expected contributions upon substantial completion				144
Pine Forest Drop Down \| Pine Forest TE Holdco LLC
Debt Instrument [Line Items]
Long-term debt				49					515
Payments for asset acquisition and transaction expenses				50
Net assets acquired less noncontrolling interest									(9)
Honeycomb Portfolio
Debt Instrument [Line Items]
Unamortized debt issuance costs					$ 9
Daggett 1 Drop Down
Debt Instrument [Line Items]
Unamortized debt issuance costs											$ 3
Payments for other fees						$ 7
Daggett 1 Drop Down \| CEG
Debt Instrument [Line Items]
Net assets acquired less noncontrolling interest						33
Daggett 1 Drop Down \| LV-Daggett Parent Holdco LLC
Debt Instrument [Line Items]
Long-term debt											220
Payments for asset acquisition					57	42
Payments for asset acquisition and transaction expenses						42
Net assets acquired less noncontrolling interest											1
Luna Valley Drop Down
Debt Instrument [Line Items]
Unamortized debt issuance costs											4
Payments for other fees							$ 9
Luna Valley Drop Down \| CEG
Debt Instrument [Line Items]
Expected contributions upon substantial completion							50
Luna Valley Drop Down \| LV-Daggett Parent Holdco LLC
Debt Instrument [Line Items]
Long-term debt											348
Payments for asset acquisition					119
Net assets acquired less noncontrolling interest											(7)
Luna Valley Drop Down \| LV-Daggett Parent Holdco LLC \| LV-Daggett Parent Holdco LLC
Debt Instrument [Line Items]
Payments for asset acquisition and transaction expenses							72				72
Rosamond South I Drop Down
Debt Instrument [Line Items]
Unamortized debt issuance costs													$ 1
Payments for other fees								$ 9
Net assets acquired less noncontrolling interest													3
Rosamond South I Drop Down \| Rosamond South Investment LLC \| Clearway Renew LLC
Debt Instrument [Line Items]
Current assets, receivables								29
Rosamond South I Drop Down \| Cash Equity Investor
Debt Instrument [Line Items]
Payments for asset acquisition													2
Rosamond South I Drop Down \| Cash Equity Investor \| Rosamond South Investment LLC \| Clearway Renew LLC
Debt Instrument [Line Items]
Current assets, receivables								41
Rosamond South I Drop Down \| CEG
Debt Instrument [Line Items]
Net assets acquired less noncontrolling interest								53
Payments to fund project reserve accounts													3
Contributions from CEG																																46
Dan’s Mountain Drop Down
Debt Instrument [Line Items]
Long-term debt															$ 125
Unamortized debt issuance costs															1
Payments for other fees										$ 2
Net assets acquired less noncontrolling interest															2
Dan’s Mountain Drop Down \| Cash Equity Investor
Debt Instrument [Line Items]
Expected contributions upon substantial completion										45
Dan’s Mountain Drop Down \| CEG
Debt Instrument [Line Items]
Net assets acquired less noncontrolling interest										26
Contributions from CEG										16
Tuolumne
Debt Instrument [Line Items]
Asset acquisition, issuance cost											$ 163
Buckthorn Solar Portfolio LLC
Debt Instrument [Line Items]
Aggregate principal amount repurchased												$ 112
Cedro Hill Repowering
Debt Instrument [Line Items]
Proceeds from the revolving credit facility																								$ 165
Long-term debt																								254
Remaining balance to distribute																								55
Payments for other fees														$ 4										4
Long-term debt, additions																																		88
Aggregate principal amount repurchased														11										72
Proceeds from debt																								27										82
Net debt issuance costs																								4
Capital expenditures																								$ 3
Asset acquisition, fund construction completion reserves														38
Cedro Hill Repowering \| Clearway Renew LLC
Debt Instrument [Line Items]
Remaining balance to distribute														26
Rosamond Central Solar Project
Debt Instrument [Line Items]
Total debt																											$ 77
Long-term debt																											115
Net assets acquired less noncontrolling interest																									$ 266
Rosamond Central Solar Project \| Rosie Central BESS
Debt Instrument [Line Items]
Payments for asset acquisition																									70
Current assets, receivables																									279
Repayment of partial loan amount																									70
Rosamond Central Solar Project \| Cash Equity Investor \| Rosie Central BESS
Debt Instrument [Line Items]
Payments for asset acquisition																									54
Rosamond Central Solar Project \| Tax Equity Investors \| Rosie Central BESS
Debt Instrument [Line Items]
Current assets, receivables																									215
Cedar Creek Drop Down
Debt Instrument [Line Items]
Long-term debt																					$ 309
Unamortized debt issuance costs																					3
Payments for other fees																					6
Net assets acquired less noncontrolling interest																					17
Asset acquisition, fund construction completion reserves																					16
Rosie Class B LLC, Due 2029
Debt Instrument [Line Items]
Long-term debt																		$ 21																30	271
Payments for other fees																		11
Rosie Class B LLC, Due 2029 \| Cash Equity Investor
Debt Instrument [Line Items]
Remaining balance to distribute																		44
Rosie Class B LLC, Due 2029 \| CEG
Debt Instrument [Line Items]
Expected contributions upon substantial completion																		56
Contributions from noncontrolling interests, net of distributions																		39
NIMH Solar, due 2024
Debt Instrument [Line Items]
Aggregate principal amount repurchased																			$ 146
Victory Pass and Arica, due 2024
Debt Instrument [Line Items]
Long-term debt																				$ 75
Unamortized debt issuance costs																										$ 4
Payments for other fees																				18
Victory Pass and Arica, due 2024 \| Cash Equity Investor
Debt Instrument [Line Items]
Expected contributions upon substantial completion																				347
Victory Pass and Arica, due 2024 \| CEG
Debt Instrument [Line Items]
Expected contributions upon substantial completion																				52
Contributions from noncontrolling interests, net of distributions																				103
Victory Pass and Arica, due 2024 \| Tax Equity Investors
Debt Instrument [Line Items]
Expected contributions upon substantial completion																				410
Texas Solar Nova 1 Drop Down
Debt Instrument [Line Items]
Unamortized debt issuance costs																							$ 1
TSN1 Class B
Debt Instrument [Line Items]
Long-term debt																							18
Payments for other fees																							5
Long-term debt, additions																							12
TSN1 Class B \| CEG
Debt Instrument [Line Items]
Remaining balance to distribute																							9
Texas Solar Nova 2
Debt Instrument [Line Items]
Long-term debt																						$ 19
Unamortized debt issuance costs																						1
Payments for other fees																						4
Texas Solar Nova 2 \| CEG
Debt Instrument [Line Items]
Contributions from noncontrolling interests, net of distributions																						9
Senior Notes 2034 \| Subsequent Event
Debt Instrument [Line Items]
Proceeds from the revolving credit facility		$ 600
Interest rate, (in percentage)		5.75%
Repayments of outstanding borrowings		$ 361
Clearway Renew LLC \| Rosamond Central Solar Project \| Rosie Central BESS
Debt Instrument [Line Items]
Payments for asset acquisition																									16
Current assets, receivables																									$ 64
Clearway Renew LLC \| Rosie Class B LLC, Due 2029 \| Rosie Class B LLC
Debt Instrument [Line Items]
Aggregate principal amount repurchased																		184
Clearway Renew LLC \| Rosie Class B LLC, Due 2029 \| Rosie TargetCo LLC
Debt Instrument [Line Items]
Payments to acquire productive assets																		279
Clearway Renew LLC \| Victory Pass and Arica, due 2024 \| VP-Arica TargetCo LLC
Debt Instrument [Line Items]
Payments to acquire productive assets																				165
Revolving Credit Facility
Debt Instrument [Line Items]
Total debt			96																										96	96	96	96	96
Term Loan \| Deriva Solar Portfolio \| Subsequent Event
Debt Instrument [Line Items]
Asset acquisition, issuance cost	$ 100
Basis spread on variable rate	2.00%
Term Loan \| Tuolumne
Debt Instrument [Line Items]
Basis spread on variable rate											1.625%
Term Loan \| Buckthorn Solar Portfolio LLC
Debt Instrument [Line Items]
Basis spread on variable rate												1.625%
Long-term debt												$ 104
Term Loan \| Capistrano Portfolio Holdco LLC
Debt Instrument [Line Items]
Asset acquisition, issuance cost																$ 121
Term Loan \| Broken Bow and Crofton Bluffs
Debt Instrument [Line Items]
Contributions from noncontrolling interests, net of distributions																63
Term Loan \| NIMH Solar, due 2024
Debt Instrument [Line Items]
Long-term debt																			137
Term Loan \| Texas Solar Nova 2
Debt Instrument [Line Items]
Long-term debt																						80
Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding			1,063																										1,063	1,063	1,063	1,063	$ 1,063
Letter of Credit \| Deriva Solar Portfolio \| Subsequent Event
Debt Instrument [Line Items]
Asset acquisition, issuance cost	$ 119
Letter of Credit \| Tuolumne
Debt Instrument [Line Items]
Asset acquisition, issuance cost											$ 22
Letter of Credit \| Buckthorn Solar Portfolio LLC
Debt Instrument [Line Items]
Long-term debt												$ 22
Letter of Credit \| Capistrano Portfolio Holdco LLC
Debt Instrument [Line Items]
Asset acquisition, issuance cost																$ 42
Letter of Credit \| Natural Gas CA Holdco LLC LC Facility
Debt Instrument [Line Items]
Maturity term																	3 years
Asset acquisition, debt outstanding																	$ 200
Debt instrument, number of additional option \| option																	2
Letter of Credit \| Natural Gas CA Holdco LLC LC Facility \| Minimum
Debt Instrument [Line Items]
Debt instrument, extension term																	1 year
Letter of Credit \| NIMH Solar, due 2024
Debt Instrument [Line Items]
Long-term debt																			$ 17
Construction Loans \| Pine Forest Drop Down
Debt Instrument [Line Items]
Long-term debt									103
Remaining balance to distribute				39
Long-term debt, additions				103
Construction Loans \| Honeycomb Portfolio
Debt Instrument [Line Items]
Long-term debt					218
Contributions from noncontrolling interests, net of distributions					59
Long-term debt, additions																													$ 38
Construction Loans \| Daggett 1 Drop Down
Debt Instrument [Line Items]
Long-term debt											92
Proceeds, Long-term Debt						31
Remaining balance to distribute						6
Long-term debt, additions						132																								$ 40
Construction Loans \| Luna Valley Drop Down
Debt Instrument [Line Items]
Long-term debt											144
Proceeds, Long-term Debt							28
Remaining balance to distribute							22
Long-term debt, additions							195																								$ 51
Construction Loans \| Rosamond South I Drop Down
Debt Instrument [Line Items]
Long-term debt													179
Proceeds, Long-term Debt								13
Long-term debt, additions								228																								$ 49
Construction Loans \| Dan’s Mountain Drop Down
Debt Instrument [Line Items]
Long-term debt, additions										18
Construction Loans \| Cedro Hill Repowering
Debt Instrument [Line Items]
Proceeds from the revolving credit facility														54
Long-term debt, additions														99
Construction Loans \| Cedar Creek Drop Down
Debt Instrument [Line Items]
Long-term debt																					112
Construction Loans \| Texas Solar Nova 1 Drop Down
Debt Instrument [Line Items]
Long-term debt																							90
Construction Loans \| TSN1 Class B
Debt Instrument [Line Items]
Long-term debt, additions																							102
Cash Equity Bridge Loan \| Pine Forest Drop Down
Debt Instrument [Line Items]
Long-term debt									102
Payments for asset acquisition									54
Proceeds, Long-term Debt				100
Long-term debt, additions			$ 52
Cash Equity Bridge Loan \| Luna Valley Drop Down
Debt Instrument [Line Items]
Long-term debt							46				64
Cash Equity Bridge Loan \| Rosamond South I Drop Down
Debt Instrument [Line Items]
Long-term debt													6
Payments for other fees													3
Cash Equity Bridge Loan \| Dan’s Mountain Drop Down
Debt Instrument [Line Items]
Long-term debt															77
Remaining balance to distribute										70
Cash Equity Bridge Loan \| Cedro Hill Repowering
Debt Instrument [Line Items]
Long-term debt														16
Cash Equity Bridge Loan \| Cedar Creek Drop Down
Debt Instrument [Line Items]
Long-term debt																					91
Cash Equity Bridge Loan \| Victory Pass and Arica, due 2024
Debt Instrument [Line Items]
Aggregate principal amount repurchased																				351
Tax Equity Bridge Loan \| Pine Forest Drop Down
Debt Instrument [Line Items]
Long-term debt									41
Proceeds, Long-term Debt				41
Tax Equity Bridge Loan \| Honeycomb Portfolio
Debt Instrument [Line Items]
Long-term debt					$ 234
Tax Equity Bridge Loan \| Daggett 1 Drop Down
Debt Instrument [Line Items]
Long-term debt											131
Proceeds, Long-term Debt						131
Tax Equity Bridge Loan \| Luna Valley Drop Down
Debt Instrument [Line Items]
Long-term debt							144				144
Tax Equity Bridge Loan \| Rosamond South I Drop Down
Debt Instrument [Line Items]
Long-term debt								276					$ 284
Tax Equity Bridge Loan \| Dan’s Mountain Drop Down
Debt Instrument [Line Items]
Long-term debt															49
Proceeds, Long-term Debt										91
Long-term debt, additions										24
Tax Equity Bridge Loan \| Cedro Hill Repowering
Debt Instrument [Line Items]
Aggregate principal amount repurchased														138
Tax Equity Bridge Loan \| Rosamond Central Solar Project
Debt Instrument [Line Items]
Long-term debt																											188
Tax Equity Bridge Loan \| Cedar Creek Drop Down
Debt Instrument [Line Items]
Long-term debt																					109
Tax Equity Bridge Loan \| Rosie Class B LLC, Due 2029
Debt Instrument [Line Items]
Long-term debt																		186
Tax Equity Bridge Loan \| Victory Pass and Arica, due 2024
Debt Instrument [Line Items]
Long-term debt																				$ 468						385
Long-term debt, additions																																		$ 62	$ 22
Tax Equity Bridge Loan \| Texas Solar Nova 1 Drop Down
Debt Instrument [Line Items]
Long-term debt																							151
Tax Equity Bridge Loan \| Texas Solar Nova 2
Debt Instrument [Line Items]
Long-term debt																						115
Tax Credit Transfer Bridge Loan \| Pine Forest Drop Down
Debt Instrument [Line Items]
Long-term debt									$ 275
Asset acquisition, partial payment of long term debt				44
Tax Credit Transfer Bridge Loan \| Pine Forest Drop Down \| Subsequent Event
Debt Instrument [Line Items]
Repayment of outstanding loan																												$ 231
Tax Equity Investors \| Pine Forest Drop Down
Debt Instrument [Line Items]
Long-term debt				38
Tax Equity Investors \| Daggett 1 Drop Down
Debt Instrument [Line Items]
Long-term debt						108
Contributions from noncontrolling interests, net of distributions						$ 38
Tax Equity Investors \| Luna Valley Drop Down
Debt Instrument [Line Items]
Long-term debt							114
Payments for asset acquisition											$ 18
Contributions from noncontrolling interests, net of distributions							$ 29
Tax Equity Investors \| Rosamond South I Drop Down
Debt Instrument [Line Items]
Long-term debt								226
Contributions from noncontrolling interests, net of distributions								$ 58
Tax Equity Investors \| Dan’s Mountain Drop Down
Debt Instrument [Line Items]
Long-term debt										90
Payments for asset acquisition															$ 7
Contributions from noncontrolling interests, net of distributions										18
Tax Equity Investors \| Cedar Creek Drop Down
Debt Instrument [Line Items]
Long-term debt																					108
Tax Equity Investors \| TSN1 Class B
Debt Instrument [Line Items]
Long-term debt																							148
Tax Equity Investors \| Texas Solar Nova 2
Debt Instrument [Line Items]
Long-term debt																						$ 130
Tax Equity Investors \| Cedro Hill TE Holdco LLC \| Cedro Hill Repowering
Debt Instrument [Line Items]
Long-term debt														$ 152
Cash Equity Investor \| Pine Forest Drop Down
Debt Instrument [Line Items]
Contributions from noncontrolling interests, net of distributions				$ 9
Cash Equity Investor \| Dan’s Mountain Drop Down
Debt Instrument [Line Items]
Payments for asset acquisition										$ 36
Line of Credit \| Letter of Credit \| Rosamond Central Solar Project
Debt Instrument [Line Items]
Bridge credit agreement, borrowing amount																											$ 41
Construction Loan \| Cedar Creek Drop Down
Debt Instrument [Line Items]
Asset acquisition, partial payment of long term debt																					2
Long-term debt, additions																					$ 110
Construction Loan \| Rosie Class B LLC, Due 2029
Debt Instrument [Line Items]
Long-term debt, additions																		$ 115
Sponsor Equity Bridge Loan \| Victory Pass and Arica, due 2024
Debt Instrument [Line Items]
Long-term debt																										483
Partial payment																										$ 133
Sponsor Equity Bridge Loan \| Texas Solar Nova 1 Drop Down
Debt Instrument [Line Items]
Long-term debt																							$ 109

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Statement of Comprehensive Income [Abstract]
Net Loss	$ (171)	$ (33)	$ (13)
Other Comprehensive Loss
Unrealized loss on derivatives and changes in accumulated OCI	(5)	(5)	(7)
Other comprehensive loss	(5)	(5)	(7)
Comprehensive Loss	(176)	(38)	(20)
Less: Comprehensive loss attributable to noncontrolling interests and redeemable noncontrolling interests	(557)	(233)	(163)
Comprehensive Income Attributable to Clearway Energy LLC	$ 381	$ 195	$ 143

- Definition

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

+ References + Details

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.

+ References + Details

- Definition

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

+ References

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The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

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-URI https://asc.fasb.org/1943274/2147480097/470-10-S99-1B

Reference 35: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 1B
-Subparagraph (SX 210.13-02(a)(5))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480097/470-10-S99-1B

Reference 36: http://www.xbrl.org/2003/role/disclosureRef
-Topic 205
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 7
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483499/205-20-50-7

Reference 37: http://www.xbrl.org/2003/role/exampleRef
-Topic 810
-SubTopic 10
-Name Accounting Standards Codification
-Section 55
-Paragraph 4J
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481175/810-10-55-4J

Reference 38: http://www.xbrl.org/2003/role/exampleRef
-Topic 810
-SubTopic 10
-Name Accounting Standards Codification
-Section 55
-Paragraph 4K
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481175/810-10-55-4K

Reference 39: http://www.xbrl.org/2003/role/disclosureRef
-Topic 220
-SubTopic 10
-Name Accounting Standards Codification
-Section 45
-Paragraph 1A
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482790/220-10-45-1A

Reference 40: http://www.xbrl.org/2003/role/disclosureRef
-Topic 220
-SubTopic 10
-Name Accounting Standards Codification
-Section 45
-Paragraph 1B
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482790/220-10-45-1B

Reference 41: http://www.xbrl.org/2003/role/disclosureRef
-Topic 230
-SubTopic 10
-Name Accounting Standards Codification
-Section 45
-Paragraph 2
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482740/230-10-45-2

Reference 42: http://www.xbrl.org/2003/role/disclosureRef
-Topic 810
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 1A
-Subparagraph (a)(1)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481203/810-10-50-1A

Reference 43: http://www.xbrl.org/2003/role/disclosureRef
-Topic 810
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 1A
-Subparagraph (c)(1)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481203/810-10-50-1A

Reference 44: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 65
-Paragraph 4
-Subparagraph (f)(4)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481538/470-20-65-4

+ Details

Leases - Schedule of Land Lease with Wholly-Owned Subsidiary (Details) $ in Millions	Dec. 31, 2025 USD ($) renewalOption	Dec. 31, 2024 USD ($)	May 31, 2023
Lessee, Lease, Description [Line Items]
Right-of-use assets, net	$ 714	$ 547
Long-term lease liabilities	816
Renewal period			5 years
Daggett 2 \| CEG
Lessee, Lease, Description [Line Items]
Right-of-use assets, net	22	22
Long-term lease liabilities	23	23
Daggett 3 \| CEG
Lessee, Lease, Description [Line Items]
Right-of-use assets, net	29	30
Long-term lease liabilities	34	34
Luna Valley Drop Down \| CEG
Lessee, Lease, Description [Line Items]
Right-of-use assets, net	16
Long-term lease liabilities	19
Mililani I \| CEG
Lessee, Lease, Description [Line Items]
Right-of-use assets, net	18	18
Long-term lease liabilities	$ 21	21
Oahu Solar
Lessee, Lease, Description [Line Items]
Number of renewal options \| renewalOption	2
Renewal period	5 years
Oahu Solar \| CEG
Lessee, Lease, Description [Line Items]
Right-of-use assets, net	$ 17	17
Long-term lease liabilities	19	19
Rosamond Centra \| CEG
Lessee, Lease, Description [Line Items]
Right-of-use assets, net	10	11
Long-term lease liabilities	12	$ 12
Rosamond South I Drop Down \| CEG
Lessee, Lease, Description [Line Items]
Right-of-use assets, net	14
Long-term lease liabilities	$ 16

Fair Value of Financial Instruments - Narrative (Details) $ in Millions	Dec. 31, 2025 USD ($)
Fair Value Disclosures [Abstract]
Percent of derivative assets using level 3 fair value inputs	8.00%
Percent of derivative liabilities using level 3 fair value inputs	93.00%
Percent of other financial instruments using level 3 fair value inputs	100.00%
Fair value assets, measured on recurring basis, valuation techniques, impact of credit reserve to fair value	$ 16

Related Party Transactions (Details) $ in Millions			12 Months Ended
Related Party Transactions (Details) $ in Millions	Dec. 12, 2025 USD ($)	Jul. 23, 2025 MW	Dec. 31, 2025 USD ($) subsidiary	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 17, 2025 USD ($)
Related Party Transaction [Line Items]
Capital expenditures			$ 196	$ 188
General and administrative			40	38	$ 35
Goat Mountain Wind Facility
Related Party Transaction [Line Items]
Power generation capacity, megawatts (over) \| MW		306
Power purchase agreement period (in years)		15 years
Remaining balance to distribute	$ 27
Capital expenditures	2
Goat Mountain Wind Facility \| Other Noncurrent Assets
Related Party Transaction [Line Items]
Remaining balance to distribute	$ 25
Related Party \| Clearway Energy Finance, Inc. Loan
Related Party Transaction [Line Items]
Loan amount						$ 22
Interest rate, (in percentage)						6.00%
Outstanding amount			22
Related Party \| RENOM
Related Party Transaction [Line Items]
Expenses from transactions with related party			82	82	73
Due to related party			8	12
Related Party \| Administrative Services Agreements
Related Party Transaction [Line Items]
Expenses from transactions with related party			26	22	20
Due to related party			3	3
Related Party \| CEG
Related Party Transaction [Line Items]
Due to related party			0	5
General and administrative			$ 24	$ 6	$ 5
Affiliated Entity \| Administrative Services Agreements
Related Party Transaction [Line Items]
Number of wholly owned subsidiaries \| subsidiary			2

Summary of Significant Accounting Policies - Schedule of Cash, Cash Equivalents and Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Accounting Policies [Abstract]
Cash and cash equivalents	$ 231	$ 332
Restricted cash	587	401
Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows	$ 818	$ 733	$ 1,051	$ 996

Revision of Previously Issued Unaudited Financial Information (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2025

Quarterly Financial Information Disclosure [Abstract]

Summary of Corrections to the Impacted Financial Statement Line Items

A summary of the corrections to the impacted financial statement line items is presented below:


	Three months ended March 31, 2025
(in millions)	As Previously Reported		Adjustments		As Revised
	(Unaudited)
Consolidated Statement of Operations
Net loss attributable to noncontrolling interests	$	(111)	$	12	$	(99)
Net income (loss) attributable to Clearway Energy LLC	$	7	$	(12)	$	(5)
Consolidated Statement of Comprehensive Income (Loss)
Comprehensive loss attributable to noncontrolling interests	$	(113)	$	12	$	(101)
Comprehensive income (loss) attributable to Clearway Energy LLC	$	3	$	(12)	$	(9)
Consolidated Balance Sheet (As of March 31, 2025)

Retained earnings	$	814	$	(12)	$	802
Noncontrolling interest	3,851		12		3,863
Total Members’ Equity	$	5,479	$	—	$	5,479
Consolidated Statements of Members’ Equity
Retained Earnings:
Net income (loss)	$	7	$	(12)	$	(5)
Retained Earnings at March 31, 2025	$	814	$	(12)	$	802
Noncontrolling Interest:
Net loss	$	(111)	$	12	$	(99)
Noncontrolling Interest at March 31, 2025	$	3,851	$	12	$	3,863


	Three months ended June 30, 2025						Six months ended June 30, 2025
(in millions)	As Previously Reported		Adjustments		As Revised		As Previously Reported		Adjustments		As Revised
	(Unaudited)						(Unaudited)
Consolidated Statement of Operations
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	$	(50)	$	5	$	(45)	$	(161)	$	17	$	(144)
Net income attributable to Clearway Energy LLC	$	69	$	(5)	$	64	$	76	$	(17)	$	59
Consolidated Statement of Comprehensive Income
Comprehensive loss attributable to noncontrolling interests and redeemable noncontrolling interests	$	(51)	$	5	$	(46)	$	(164)	$	17	$	(147)
Comprehensive income attributable to Clearway Energy LLC	$	53	$	(5)	$	48	$	56	$	(17)	$	39
Consolidated Balance Sheet (As of June 30, 2025)
Redeemable noncontrolling interest in subsidiaries	$	38	$	7	$	45
Retained earnings	778		(17)		761
Noncontrolling interest	4,152		10		4,162
Total Members’ Equity	$	5,575	$	(7)	$	5,568
Consolidated Statements of Members’ Equity
Retained Earnings:
Net income	$	69	$	(5)	$	64
Retained Earnings at June 30, 2025	$	778	$	(17)	$	761
Noncontrolling Interest:
Net loss	$	(37)	$	(2)	$	(39)
Noncontrolling Interest at June 30, 2025	$	4,152	$	10	$	4,162


	Three months ended September 30, 2025						Nine months ended September 30, 2025
(in millions)	As Previously Reported		Adjustments		As Revised		As Previously Reported		Adjustments		As Revised
	(Unaudited)						(Unaudited)
Consolidated Statement of Operations
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	$	(322)	$	6	$	(316)	$	(483)	$	23	$	(460)
Net income attributable to Clearway Energy LLC	$	351	$	(6)	$	345	$	427	$	(23)	$	404
Consolidated Statement of Comprehensive Income
Comprehensive loss attributable to noncontrolling interests and redeemable noncontrolling interests	$	(322)	$	6	$	(316)	$	(486)	$	23	$	(463)
Comprehensive income attributable to Clearway Energy LLC	$	346	$	(6)	$	340	$	402	$	(23)	$	379
Consolidated Balance Sheet (As of September 30, 2025)
Redeemable noncontrolling interest in subsidiaries	$	74	$	30	$	104
Retained earnings	1,039		(23)		1,016
Noncontrolling interest	4,156		(7)		4,149
Total Members’ Equity	$	5,697	$	(30)	$	5,667
Consolidated Statements of Members’ Equity
Retained Earnings:
Net income	$	351	$	(6)	$	345
Retained Earnings at September 30, 2025	$	1,039	$	(23)	$	1,016
Noncontrolling Interest:
Net loss	$	(137)	$	(17)	$	(154)
Noncontrolling Interest at September 30, 2025	$	4,156	$	(7)	$	4,149

Acquisitions and Dispositions -Schedule of Recognized Identified Assets Acquired and Liabilities Assumed (Details) - USD ($) $ in Millions															12 Months Ended
	Dec. 17, 2025	Oct. 15, 2025	Sep. 04, 2025	Aug. 13, 2025	Jul. 16, 2025	Jun. 10, 2025	Apr. 29, 2025	Mar. 20, 2025	Nov. 18, 2024	Apr. 16, 2024	Mar. 15, 2024	Dec. 01, 2023	Oct. 31, 2023	Jun. 30, 2023	Dec. 31, 2025
Business Acquisition [Line Items]
Acquisition															$ 351
Pine Forest Drop Down
Business Acquisition [Line Items]
Unamortized debt issuance costs						$ 6
Pine Forest Drop Down \| Cash Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt						102
Construction in progress						550
Pine Forest Drop Down \| Construction Loans
Business Acquisition [Line Items]
Long-term debt						103
Pine Forest Drop Down \| Tax Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt						41
Pine Forest Drop Down \| Tax Credit Transfer Bridge Loan
Business Acquisition [Line Items]
Long-term debt						275
Honeycomb Portfolio
Business Acquisition [Line Items]
Unamortized debt issuance costs		$ 9
Honeycomb Portfolio \| Cash Equity Bridge Loan
Business Acquisition [Line Items]
Construction in progress		473
Honeycomb Portfolio \| Construction Loans
Business Acquisition [Line Items]
Long-term debt		218
Honeycomb Portfolio \| Tax Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt		234
Daggett 1 Drop Down
Business Acquisition [Line Items]
Unamortized debt issuance costs							$ 3
Daggett 1 Drop Down \| Cash Equity Bridge Loan
Business Acquisition [Line Items]
Construction in progress							221
Daggett 1 Drop Down \| Construction Loans
Business Acquisition [Line Items]
Long-term debt							92
Daggett 1 Drop Down \| Tax Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt							131
Luna Valley Drop Down
Business Acquisition [Line Items]
Unamortized debt issuance costs							4
Luna Valley Drop Down \| Cash Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt			$ 46				64
Construction in progress							338
Luna Valley Drop Down \| Construction Loans
Business Acquisition [Line Items]
Long-term debt							144
Luna Valley Drop Down \| Tax Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt			$ 144				144
Rosamond South I Drop Down
Business Acquisition [Line Items]
Net liabilities assumed								$ 3
Unamortized debt issuance costs								1
Rosamond South I Drop Down \| Cash Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt								6
Construction in progress								495
Rosamond South I Drop Down \| Construction Loans
Business Acquisition [Line Items]
Long-term debt								179
Rosamond South I Drop Down \| Tax Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt				$ 276				284
Dan’s Mountain Drop Down
Business Acquisition [Line Items]
Property, plant and equipment									$ 152
Right-of-use assets, net									3
Total assets acquired									155
Long-term debt									125
Long-term lease liabilities									3
Other current and non-current liabilities									29
Total liabilities assumed									157
Net liabilities assumed									2
Construction in progress									150
Unamortized debt issuance costs									1
Dan’s Mountain Drop Down \| Cash Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt									77
Dan’s Mountain Drop Down \| Tax Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt									$ 49
Rosamond Central Solar Project
Business Acquisition [Line Items]
Property, plant and equipment												$ 275
Total assets acquired												275
Long-term debt														$ 115
Other current and non-current liabilities												9
Total liabilities assumed												9
Net liabilities assumed												266
Construction in progress												$ 272
Rosamond Central Solar Project \| Tax Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt														$ 188
Victory Pass and Arica Drop Down
Business Acquisition [Line Items]
Cash													$ 1
Property, plant and equipment													937
Right-of-use assets, net													4
Derivative assets													1
Other current and non-current assets													6
Total assets acquired													949
Long-term debt													864
Long-term lease liabilities													4
Other current and non-current liabilities													82
Total liabilities assumed													950
Net liabilities assumed													(1)
Construction in progress													893
Unamortized debt issuance costs													4
Victory Pass and Arica Drop Down \| Cash Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt													483
Victory Pass and Arica Drop Down \| Tax Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt													$ 385
Cedar Creek Drop Down
Business Acquisition [Line Items]
Restricted cash										$ 1
Property, plant and equipment										311
Right-of-use assets, net										6
Derivative assets										14
Other current and non-current assets										14
Total assets acquired										346
Long-term debt										309
Long-term lease liabilities										7
Other current and non-current liabilities										13
Total liabilities assumed										329
Net liabilities assumed										17
Unamortized debt issuance costs										3
Cedar Creek Drop Down \| Cash Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt										91
Cedar Creek Drop Down \| Construction Loans
Business Acquisition [Line Items]
Long-term debt										112
Cedar Creek Drop Down \| Tax Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt										$ 109
Texas Solar Nova 2 Drop Down
Business Acquisition [Line Items]
Restricted cash											$ 1
Property, plant and equipment											280
Right-of-use assets, net											21
Derivative assets											6
Other current and non-current assets											4
Total assets acquired											312
Long-term debt											194
Long-term lease liabilities											19
Other current and non-current liabilities											27
Total liabilities assumed											240
Net liabilities assumed											72
Unamortized debt issuance costs											1
Texas Solar Nova 2 Drop Down \| Tax Equity Bridge Loan
Business Acquisition [Line Items]
Long-term debt											115
Texas Solar Nova 2 Drop Down \| Term Loan
Business Acquisition [Line Items]
Long-term debt											$ 80
Pine Forest TE Holdco LLC \| Pine Forest Drop Down
Business Acquisition [Line Items]
Restricted cash						1
Property, plant and equipment						560
Right-of-use assets, net						17
Derivative assets						6
Total assets acquired						584
Long-term debt	$ 49					515
Long-term lease liabilities						18
Derivative liabilities						1
Other current and non-current liabilities						54
Total liabilities assumed						588
Other comprehensive income						5
Net liabilities assumed						$ (9)
Honeycomb 1 Holdco LLC \| Honeycomb Portfolio
Business Acquisition [Line Items]
Cash		1
Property, plant and equipment		480
Right-of-use assets, net		3
Derivative assets		4
Other current and non-current assets		7
Total assets acquired		495
Long-term debt		443
Long-term lease liabilities		3
Derivative liabilities		7
Other current and non-current liabilities		47
Total liabilities assumed		500
Other comprehensive income		(3)
Net liabilities assumed		$ (2)
LV-Daggett Parent Holdco LLC \| Daggett 1 Drop Down
Business Acquisition [Line Items]
Cash							1
Property, plant and equipment							223
Other current and non-current assets							8
Total assets acquired							232
Long-term debt							220
Derivative liabilities							6
Other current and non-current liabilities							11
Total liabilities assumed							237
Other comprehensive income							(6)
Net liabilities assumed							1
LV-Daggett Parent Holdco LLC \| Luna Valley Drop Down
Business Acquisition [Line Items]
Restricted cash							8
Property, plant and equipment							346
Right-of-use assets, net							16
Other current and non-current assets							22
Total assets acquired							392
Long-term debt							348
Long-term lease liabilities							18
Derivative liabilities							8
Other current and non-current liabilities							33
Total liabilities assumed							407
Other comprehensive income							(8)
Net liabilities assumed							(7)
Rosie South TargetCo LLC \| Rosamond South I Drop Down
Business Acquisition [Line Items]
Property, plant and equipment								507
Right-of-use assets, net								17
Other current and non-current assets								11
Total assets acquired								535
Long-term debt								468
Long-term lease liabilities								19
Derivative liabilities								4
Other current and non-current liabilities								51
Total liabilities assumed								542
Other comprehensive income								(4)
Net liabilities assumed								$ (3)
Catalina Solar Investment LLC \| Catalina Solar Acquisition
Business Acquisition [Line Items]
Cash					$ 15
Acquisition					175
Right-of-use assets, net					107
Other current and non-current assets					6
Total assets acquired					303
Long-term lease liabilities					173
Other current and non-current liabilities					2
Total liabilities assumed					175
Net liabilities assumed					$ 128
Washington Wind LLC \| Tuolumne
Business Acquisition [Line Items]
Property, plant and equipment							37
Acquisition							176
Right-of-use assets, net							5
Other current and non-current assets							1
Total assets acquired							219
Long-term lease liabilities							4
Other current and non-current liabilities							4
Total liabilities assumed							8
Net liabilities assumed							$ 211

Long-term Debt (Tables)

12 Months Ended

Dec. 31, 2025

Debt Disclosure [Abstract]

Schedule of Long-Term Debt

The Company’s borrowings, including short-term and long-term portions, consisted of the following:


	Maturity Date	December 31, 2025		December 31, 2024		Interest rate % (a)
		(In millions, except rates)
Intercompany Note with Clearway, Inc.	2026	$	6	$	—	3.61	%
Senior Notes	2028-2032	2,125		2,125		3.750% - 4.750%
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility (b) (c)	2028	361		—		S+1.750%
Non-recourse facility-level debt:
Fixed rate	2031-2040	3,001		3,190		2.339% - 8.000%
Variable rate	2026-2033	3,187		1,920		S+1.375% - 2.750%
Total debt		8,680		7,235
Less current maturities		(714)		(430)
Less net debt issuance costs		(70)		(57)
Add premiums (d)		2		2
Total long-term debt		$	7,898	$	6,750

(a) As of December 31, 2025, S+ equals SOFR plus x%.

(b) Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement, and only applies to outstanding borrowings.

(d) Premiums relate to the 2028 Senior Notes.

Schedule of Swaps Related to the Company's Facility Level Debt

The following table summarizes the swaps, some of which are forward starting as indicated, related to the Company’s facility level debt and the potential refinancing of its Senior Notes:


	% of Principal		Fixed Interest Rate		Floating Interest Rate	Notional Amount at December 31, 2025 (In millions)		Effective Date	Maturity Date
Avra Valley	85	%	2.20	%	SOFR	$	23	March 31, 2023	January 31, 2031
Alta Wind Asset Management	100	%	2.22	%	SOFR	8		May 22, 2013	May 15, 2031
Buckthorn Solar	100	%	2.63	%	SOFR	100		April 9, 2025	July 31, 2043
Capistrano Portfolio Holdco	100	%	Various		SOFR	106		October 24, 2024	September 30, 2033
Carlsbad Energy Holdings	100	%	Various		SOFR	46		Various	September 30, 2027
Cedar Creek	100	%	3.02	%	SOFR	106		April 30, 2024	March 31, 2049
Cedro Hill	85	%	Various		SOFR	77		Various	September 30, 2044
Clearway Energy Operating (a)	—	%	Various		SOFR	1,093		Various	Various
Daggett 1	95	%	Various		SOFR	126		Various	Various
Daggett 2	87	%	Various		SOFR	134		March 29, 2024	March 31, 2043
Daggett 3	84	%	Various		SOFR	181		September 30, 2024	September 30, 2043
Honeycomb Portfolio (a)	85	%	Various		SOFR	694		Various	Various
Kansas South	75	%	1.93	%	SOFR	9		June 28, 2013	December 31, 2030
Luna Valley	95	%	Various		SOFR	185		Various	Various
Mililani Class B	97	%	Various		SOFR	85		Various	Various
NIMH Solar	100	%	3.25	%	SOFR	111		June 11, 2024	January 31, 2033
Oahu Solar	96	%	2.47	%	SOFR	72		November 30, 2019	October 31, 2040
Pine Forest	85	%	Various		SOFR	88		November 28, 2025	March 31, 2050
Rosie Class B	93	%	Various		SOFR	172		Various	Various
Rosie South	90	%	Various		SOFR	206		Various	Various
South Trent	90	%	Various		SOFR	13		Various	June 30, 2028
TSN1 Class B	96	%	Various		SOFR	163		March 29, 2024	September 30, 2043
Viento Funding II	90	%	2.53	%	SOFR	129		Various	December 31, 2032
Tuolumne	100	%	Various		SOFR	153		April 29, 2025	March 31, 2040
Total						$	4,080

(a) As of December 31, 2025, the notional amount includes forward swaps that are not included in the percentage of outstanding principal disclosed.

Schedule of Annual Payments Based on the Maturities of NRG Yield's Debt

Annual Maturities

Annual payments based on the maturities of the Company’s debt, for the years ending after December 31, 2025, are as follows:


	(In millions)
2026 (a)	$	1,145
2027	364
2028	2,022
2029	863
2030	995
Thereafter	3,291
Total	$	8,680

Schedule I - Condensed Financial Statements - P/L (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2025	Jun. 30, 2025	Mar. 31, 2025	Jun. 30, 2025	Sep. 30, 2025	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Condensed Income Statements, Captions [Line Items]
Other income, net						$ 29	$ 48	$ 52
Total other income						(335)	(229)	(279)
Net Income Attributable to Clearway Energy LLC	$ 345	$ 64	$ (5)	$ 59	$ 404	384	203	149
Clearway Energy LLC
Condensed Income Statements, Captions [Line Items]
Equity in earnings of consolidated subsidiaries						381	192	126
Other income, net						3	11	23
Total other income						384	203	149
Net Income Attributable to Clearway Energy LLC						$ 384	$ 203	$ 149

- Definition

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

+ References

Reference 1: http://www.xbrl.org/2003/role/exampleRef
-Topic 946
-SubTopic 830
-Name Accounting Standards Codification
-Section 55
-Paragraph 10
-Publisher FASB
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Reference 2: http://www.xbrl.org/2003/role/exampleRef
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+ Details

Summary of Significant Accounting Policies (Policies)	12 Months Ended
Summary of Significant Accounting Policies (Policies)	Dec. 31, 2025
Accounting Policies [Abstract]
Basis of Presentation	The Company’s consolidated financial statements have been prepared in accordance with GAAP. The FASB ASC is the source of authoritative 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 GAAP for SEC registrants.
Principles of Consolidation	The consolidated financial statements include the Company’s accounts and operations and those of its subsidiaries in which it has a controlling financial interest. All significant intercompany transactions and balances have been eliminated in consolidation. The usual condition for a controlling financial interest is ownership of the 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, the Company applies the guidance of ASC 810, Consolidations, to determine when an entity that is insufficiently capitalized or not controlled through its voting interests, referred to as a variable interest entity, or VIE, should be consolidated.
Cash, Cash Equivalents and Restricted Cash	Cash, Cash Equivalents and Restricted Cash Cash and cash equivalents include highly liquid investments with an original maturity of three months or less at the time of purchase. Restricted cash consists primarily of funds held to satisfy the requirements of certain debt agreements and funds held within the Company’s facilities that are restricted in their use.
Accounts Receivable - Trade and Allowance for Credit Loss	Accounts Receivable — Trade and Allowance for Credit Losses Accounts receivable — trade are reported on the consolidated balance sheet at the invoiced amount adjusted for any write-offs and the allowance for credit losses. The majority of the Company’s customers typically receive invoices monthly with payment due within 30 days. The allowance for credit losses is reviewed periodically based on amounts past due and their significance.
Inventory	Inventory Inventory consists of spare parts and is valued at weighted average cost, unless evidence indicates that the weighted average cost will not be recovered with a normal profit in the ordinary course of business. Inventory is removed when used for repairs, maintenance or capital projects.
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment are stated at cost, however, impairment adjustments are recorded whenever events or changes in circumstances indicate that their carrying amounts may not be recoverable. Significant additions or improvements extending asset lives are capitalized as incurred, while repairs and maintenance that do not improve or extend the life of the respective asset are charged to expense as incurred. Depreciation is computed using the straight-line method over the estimated useful lives. Certain assets and their related accumulated depreciation amounts are adjusted for asset retirements and disposals with the resulting gain or loss included in cost of operations in the consolidated statements of operations. For further discussion of the Company’s property, plant and equipment refer to Note 4, Property, Plant and Equipment. Interest incurred on funds borrowed to finance capital projects is capitalized until the project under construction is ready for its intended use. The amount of interest capitalized for the years ended December 31, 2025, 2024 and 2023 was $51 million, $28 million and $36 million, respectively. Construction in-progress represents cumulative construction costs, including the costs incurred for the purchase of major equipment and engineering costs and capitalized interest. Once the project achieves commercial operation, the Company reclassifies the amounts recorded in construction in progress to facilities and equipment.
Asset Impairments	Asset Impairments Long-lived assets that are held and used are reviewed for impairment whenever events or changes in circumstances indicate their carrying amounts may not be recoverable. Such reviews are performed in accordance with ASC 360, Property, Plant and Equipment. An impairment loss is indicated if the total future estimated undiscounted cash flows expected from an asset are less than its carrying amount. An impairment charge is measured as the excess of an asset’s carrying amount over its 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 appraisals, sales prices of similar assets and present value techniques. For further discussion of the Company’s long-lived asset impairments, refer to Note 9, Asset Impairments. Investments accounted for by the equity method are reviewed for impairment in accordance with ASC 323, Investments-Equity Method and Joint Ventures, 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.
Debt Issuance Costs	Debt Issuance Costs Debt issuance costs are capitalized and amortized as interest expense on a basis which approximates the effective interest method over the term of the related debt. Debt issuance costs related to the long-term debt are presented as a direct deduction from the carrying amount of the related debt. Debt issuance costs related to the senior secured revolving credit facility line of credit are recorded as a non-current asset on the consolidated balance sheet and are amortized over the term of the credit facility.
Intangible Assets	Intangible Assets Intangible assets represent contractual rights held by the Company. The Company recognizes specifically identifiable intangible assets, including PPAs, leasehold rights, emission allowances, RECs and development rights when specific rights and contracts are acquired. These intangible assets are amortized primarily on a straight-line basis.
Income Taxes	Income Taxes The Company is classified as a partnership for federal and state income tax purposes. Therefore, federal and most state income taxes are assessed at the partner level. The franchise tax imposed by the state of Texas, however, is being assessed at the level of certain operating subsidiaries of the Company, and therefore reflected as an income tax expense or benefit of the Company. For the year ended December 31, 2025, the Company recorded a deferred tax benefit of $1 million, which resulted in a cumulative deferred tax liability of $2 million with respect to future years. For the year ended December 31, 2024, the Company recorded a deferred tax expense of $1 million, which resulted in a cumulative deferred tax liability of $3 million with respect to future years.
Revenue Recognition and Contract Amortization	Revenue Recognition Revenue from Contracts with Customers The Company applies the guidance in ASC 606, Revenue from Contracts with Customers, or Topic 606, when recognizing revenue associated with its contracts with customers. The Company’s policies with respect to its various revenue streams are detailed below. In general, the Company 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. Flexible Generation Segment Revenues The majority of the facilities in the Flexible Generation segment commenced merchant operations during 2023 following the expiration of the PPAs. These facilities generate revenues from selling electricity and/or RA to the CAISO and to public utility and load serving entities, as the power is delivered at the interconnection point. Power Purchase Agreements, or PPAs The majority of the Company’s revenues are obtained through PPAs or similar contractual agreements. Energy, capacity and, where applicable, renewable attributes, from the majority of the Company’s renewable energy assets and certain facilities in the Flexible Generation segment are sold through long-term PPAs and tolling agreements to a single counterparty, which is often a utility or commercial customer. Certain revenue agreements also provide for the sale of BESS capacity. As discussed above, the majority of the facilities in the Flexible Generation segment commenced merchant operations during 2023 following the expiration of the PPAs. The majority of these PPAs are accounted for as operating leases as the Company retained its historical lease assessments and classification upon adoption of ASC 842, Leases. ASC 842 requires the minimum lease payments received to be amortized over the term of the lease and contingent rentals are recorded when the achievement of the contingency becomes probable. The Company’s BESS arrangements include variable payments not based on an index or rate and sales-type lease treatment would result in a loss at lease commencement. As a result, the Company accounts for these arrangements as operating leases under ASC 842. Judgment is required by management in determining the economic life of each generating facility, in evaluating whether certain lease provisions constitute minimum payments or represent contingent rent and other factors in determining whether a contract contains a lease and whether the lease is an operating lease or finance lease. Certain of these PPAs have no minimum lease payments and all of the lease revenue under these PPAs is recorded as contingent rent on an actual basis when the electricity is delivered. The contingent lease revenue recognized in the years ended December 31, 2025, 2024 and 2023 was $797 million, $831 million and $780 million, respectively. See Note 15, Leases, for additional information related to the Company’s PPAs accounted for as leases. Renewable Energy Credits, or RECs Renewable energy credits, or RECs, are usually sold through long-term PPAs or through REC contracts with counterparties. Revenue from the sale of self-generated RECs is recognized when the related energy is generated and simultaneously delivered even in cases where there is a certification lag as it has been deemed to be perfunctory. In a bundled contract to sell energy, capacity and/or self-generated RECs, all performance obligations are deemed to be delivered at the same time and hence, timing of recognition of revenue for all performance obligations is the same and occurs over time. In such cases, it is unnecessary to allocate transaction price to multiple performance obligations. Contract Amortization Assets and liabilities recognized from power sales agreements assumed through acquisitions relating to the sale of electric capacity and energy in future periods arising from differences in contract and market prices are amortized to revenue over the term of each underlying contract based on actual generation and/or contracted volumes or on a straight-line basis, where applicable.
Derivatives Financial Instruments	Derivative Financial Instruments The Company accounts for derivative financial instruments under ASC 815, Derivatives and Hedging, or ASC 815, which requires the Company to record all derivatives on the balance sheet at fair value unless they qualify for a NPNS exception. Changes in the fair value of non-hedge derivatives are immediately recognized in earnings. Changes in the fair value of derivatives accounted for as hedges, if elected for hedge accounting, are deferred and recorded as a component of accumulated OCI/OCL until the hedged transactions occur and are recognized in earnings. The Company’s primary derivative financial instruments are interest rate instruments used to mitigate variability in earnings due to fluctuations in interest rates and energy-related instruments used to mitigate variability in earnings due to fluctuations in power market prices or natural gas market prices. Certain derivative contracts contain provisions providing the counterparties a lien on specific assets as collateral. On an ongoing basis, the Company qualitatively assesses the effectiveness of its derivatives that are designated as hedges for accounting purposes in order to determine that each derivative continues to be highly effective in offsetting changes in cash flows of hedged items. If necessary, the Company will perform an analysis to measure the statistical correlation between the derivative and the associated hedged item to determine the effectiveness of such a contract designated as a hedge. The Company will discontinue hedge accounting if it is determined that the hedge is no longer effective. In this case, the gain or loss previously deferred in accumulated OCI/OCL would be frozen until the underlying hedged item is delivered unless the transaction being hedged is no longer probable of occurring in which case the amount in accumulated OCI/OCL would be immediately reclassified into earnings. If the derivative financial instrument is terminated, the effective portion of this derivative deferred in accumulated OCI/OCL will be frozen until the underlying hedged item is delivered. 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 financial 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. Cash flows from derivative financial instruments, including derivatives designated as cash flow hedges and derivatives not designated as cash flow hedges, are classified as operating activities in the consolidated statements of cash flows.
Concentrations of Credit Risk	Concentrations of Credit Risk Financial instruments which potentially subject the Company to concentrations of credit risk consist primarily of accounts receivable — trade and derivative financial instruments, which are concentrated within entities engaged in the energy and financial industries. These industry concentrations may impact the 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. In addition, many of the Company’s facilities have only one customer. 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) monitoring of counterparties’ credit limits on as needed basis; (iii) as applicable, 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. Counterparty credit exposure includes credit risk exposure under certain long-term agreements, including solar and other PPAs. As external sources or observable market quotes are not available to estimate such exposure, the Company estimates the exposure related to 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. A significant portion of these energy-related commodity contracts are with utilities with strong credit quality and public utility commission or other regulatory support. However, such regulated utility counterparties can be impacted by changes in government regulations or adverse financial conditions, which the Company is unable to predict. Certain subsidiaries of the Company sell the output of their facilities to PG&E, a significant counterparty of the Company, under long-term PPAs, and PG&E’s credit rating is below investment-grade.
Fair Value of Financial Instruments	Fair Value of Financial Instruments The carrying amount of cash and cash equivalents, restricted cash, accounts receivable — trade, accounts receivable — affiliates accounts payable — trade, accounts payable — affiliates and accrued expenses and other current liabilities approximate fair value because of the short-term maturity of these instruments.
Asset Retirement Obligations	Asset Retirement Obligations Asset retirement obligations, or AROs, are accounted for 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, other than when an ARO is assumed in an acquisition of the related long-lived asset, the asset retirement cost is capitalized 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. The Company’s AROs are primarily related to the future dismantlement of equipment on leased property and environmental obligations related to site closures and fuel storage facilities. The Company records AROs as part of other non-current liabilities on its consolidated balance sheet.
Guarantees	Guarantees The Company enters into various contracts that include indemnification and guarantee provisions as a routine part of its business activities. Examples of these contracts include operation and maintenance agreements, service agreements, commercial sales arrangements 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. Because many of the guarantees and indemnities the Company 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 agreed upon in the contracts mentioned above. For those guarantees and indemnities that do not limit the liability exposure, the Company may not be able to estimate what the liability would be, until a claim is made for payment or performance, due to the contingent nature of these contracts.
Investments Accounted for by the Equity Method	Investments Accounted for by the Equity Method The Company has investments in various energy facilities accounted for by the equity method, several of which are VIEs, where the Company is not a primary beneficiary, as described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. The equity method of accounting is applied to these investments in affiliates because the ownership structure prevents the Company from exercising a controlling influence over the operating and financial policies of the facilities. Under this method, equity in pre-tax income or losses of the investments is 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.
Sale-Leaseback Arrangements	Sale-Leaseback Arrangements The Company is party to sale-leaseback arrangements that provide for the sale of certain assets to a third-party and simultaneous leaseback to the Company. In accordance with ASC 842-40, Sale-Leaseback Transactions, if the seller-lessee retains, through the leaseback, substantially all of the benefits and risks incident to the ownership of the property sold, the sale-leaseback transaction is accounted for as a financing arrangement. An example of this type of continuing involvement would include an option to repurchase the assets or the buyer-lessor having the option to sell the assets back to the Company. This provision is included in most of the Company’s sale-leaseback arrangements. As such, the Company accounts for these arrangements as financings. Under the financing method, the Company does not recognize as income any of the sale proceeds received from the lessor that contractually constitutes payment to acquire the assets subject to these arrangements. Instead, the sale proceeds received are accounted for as financing obligations and leaseback payments made by the Company are allocated between interest expense and a reduction to the financing obligation. Interest on the financing obligation is calculated using the Company’s incremental borrowing rate at the inception of the arrangement on the outstanding financing obligation. Judgment is required to determine the appropriate borrowing rate for the arrangement and in determining any gain or loss on the transaction that would be recorded either at the end of or over the lease term.
Asset Acquisitions	Asset Acquisitions The Company accounts for its acquisitions in accordance with ASC 805, Business Combinations, or ASC 805. For third-party acquisitions, ASC 805 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. No goodwill is recognized, and excess purchase price or negative goodwill are allocated to the acquired assets on a relative fair value basis. For acquisitions that relate to entities under common control, the difference between the cash paid and historical value of the entities’ equity is recorded as a distribution/contribution from/to CEG with the offset to contributed capital.
Tax Equity Arrangements	Tax Equity Arrangements Certain portions of the Company’s redeemable noncontrolling interest in subsidiaries and noncontrolling interest represent third-party interests in the net assets under tax equity arrangements, which are consolidated by the Company, that have been entered into to finance the cost of facilities eligible for certain tax credits and benefits. The Company has determined that the provisions in the contractual agreements of these redeemable noncontrolling interests and noncontrolling interests represent substantive profit sharing arrangements. Further, the Company has determined that the appropriate methodology for calculating the redeemable noncontrolling interest and noncontrolling interest that reflects the substantive profit sharing arrangements is a balance sheet approach utilizing the hypothetical liquidation at book value, or HLBV, method. Under the HLBV method, the amounts reported as redeemable noncontrolling interest and noncontrolling interest represent the amounts the investors 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 determined in accordance with GAAP. The investors’ interests in the results of operations of the funding structures are determined as the difference in redeemable noncontrolling interest and noncontrolling interest at the start and end of each reporting period, after taking into account any capital transactions between the structures and the funds’ investors. The calculations utilized to apply the HLBV method include estimated calculations of taxable income or losses for each reporting period. In addition, in certain circumstances, the Company and its partners in the tax equity arrangements agree that certain tax benefits are to be utilized outside of the tax equity arrangements, which may result in differences in the amount an investor would hypothetically receive at the initial balance sheet date calculated strictly in accordance with related contractual agreements. These differences are recognized in the consolidated statements of operations using a systematic and rational method over the period during which the investor is expected to achieve its target return.
Use of Estimates	Use of Estimates The preparation of consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions. These estimates and assumptions impact the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities as of the date of the consolidated financial statements. They also impact the reported amounts of net earnings during the reporting periods. Actual results could be different 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, uncollectible accounts, AROs, acquisition accounting, fair value of financial instruments and legal costs incurred in connection with recorded loss contingencies, among others. In addition, estimates are used to test long-lived assets 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.
Recent Accounting Standards Not Yet Adopted	Recent Accounting Standards Not Yet Adopted In December 2025, the FASB issued ASU No 2025-10, Government Grants - (Topic 832): Accounting for Government Grants Received by Business Entities. The amendment establishes the accounting guidance for governmental grants received by a business entity. This guidance is effective for annual reporting periods beginning after December 15, 2028 and interim reporting periods within the annual reporting period. The amendment may be applied on a modified prospective approach, a modified retrospective approach or retrospectively. Early adoption is permitted in both interim and annual reporting periods. As of December 31, 2025, the Company has not elected to early adopt the standard and is evaluating the effect of the new guidance on its consolidated financial statements. In September 2025, the FASB issued ASU No. 2025-06, Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Targeted Improvements to the Accounting for Internal-Use Software. The amendment clarifies when software costs should be capitalized and requires certain disclosures for all capitalized internal-use software costs. This guidance may be applied prospectively, retrospectively or on a modified retrospective basis and is effective for annual reporting periods in fiscal years beginning after December 15, 2027. The Company intends to early adopt ASU 2025-06 prospectively, effective January 1, 2026. The adoption is not expected to have an impact on the Company’s financial statements. In September 2025, the FASB issued ASU No. 2025-07, Derivatives and Hedging (Topic 815) and Revenue from Contracts with Customers (Topic 606): Derivatives Scope Refinements and Scope Clarification for Share-Based Noncash Consideration from a Customer in a Revenue Contract. The amendment expands the derivative scope exceptions and clarifies when an entity should apply the guidance in ASC 606, Revenue from Contracts with Customers, to contracts with share-based noncash consideration from a customer for the transfer of goods or services. This guidance may be applied either prospectively or on a modified retrospective basis and is effective for annual reporting periods in fiscal years beginning after December 15, 2026. The Company intends to early adopt ASU 2025-07 prospectively, effective January 1, 2026. The adoption is not expected to have an impact on the Company’s financial statements. In November 2024, the FASB issued ASU No 2024-03, Income Statement - Reporting Comprehensive Income-Expense Disaggregation Disclosures (Subtopic 220-40). The amendment requires certain expenses presented on the face of the income statement to be disaggregated in the notes to the financial statements. This guidance is effective for annual reporting periods beginning after December 15, 2026 and interim periods within annual reporting periods beginning after December 15, 2027. The amendments may be applied either prospectively to financial statements issued for reporting periods after the effective date of this ASU or retrospectively to all prior periods presented in the financial statements. As of December 31, 2025, the Company has not elected to early adopt the standard and is evaluating the effect of the new guidance on its consolidated financial statements.

Members' Equity - Schedule of Dividends Paid (Details) - $ / shares	Dec. 31, 2025	Sep. 30, 2025	Jun. 30, 2025	Mar. 31, 2025	Dec. 31, 2024	Sep. 30, 2024	Jun. 30, 2024	Mar. 31, 2024	Dec. 31, 2023	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023
Common Class A
Class of Stock [Line Items]
Distributions per Class A, B, C and D unit (in dollars per share)	$ 0.4528	$ 0.4456	$ 0.4384	$ 0.4312	$ 0.4240	$ 0.4171	$ 0.4102	$ 0.4033	$ 0.3964	$ 0.3891	$ 0.3818	$ 0.3745
Common Class B
Class of Stock [Line Items]
Distributions per Class A, B, C and D unit (in dollars per share)	0.4528	0.4456	0.4384	0.4312	0.4240	0.4171	0.4102	0.4033	0.3964	0.3891	0.3818	0.3745
Common Class C
Class of Stock [Line Items]
Distributions per Class A, B, C and D unit (in dollars per share)	0.4528	0.4456	0.4384	0.4312	0.4240	0.4171	0.4102	0.4033	0.3964	0.3891	0.3818	0.3745
Common Class D
Class of Stock [Line Items]
Distributions per Class A, B, C and D unit (in dollars per share)	$ 0.4528	$ 0.4456	$ 0.4384	$ 0.4312	$ 0.4240	$ 0.4171	$ 0.4102	$ 0.4033	$ 0.3964	$ 0.3891	$ 0.3818	$ 0.3745

- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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Reference 3: http://www.xbrl.org/2009/role/commonPracticeRef
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 6: http://www.xbrl.org/2003/role/recommendedDisclosureRef
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Reference 8: http://www.xbrl.org/2009/role/commonPracticeRef
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Reference 14: http://www.xbrl.org/2003/role/disclosureRef
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Reference 15: http://www.xbrl.org/2003/role/disclosureRef
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+ Details

Leases - Schedule of Lease Information and Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Leases [Abstract]
Operating lease cost - Fixed	$ 51	$ 31	$ 40
Operating lease cost - Variable	15	12	11
Total lease cost	66	43	51
Cash paid for operating leases	50	34	$ 30
ASSETS
Right-of-use assets - operating leases, net	714	547
Liabilities [Abstract]
Short-term lease liability - operating leases	20	10
Long-term lease liabilities	796	569
Total lease liabilities	$ 816	$ 579
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Long-term lease liabilities	Long-term lease liabilities
Weighted average remaining lease term (in years)	25 years	26 years
Weighted average discount rate	5.70%	4.50%

Fair Value of Financial Instruments - Schedule of Fair Value Measurement Inputs and Valuation Techniques (Details) - Level 3 $ in Millions	Dec. 31, 2025 USD ($) $ / MWh $ / BTU MWh	Dec. 31, 2024 USD ($) $ / MWh $ / BTU MWh
Minimum \| Measurement Input, Commodity Forward Price \| Valuation Technique, Option Pricing Model
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| $ / BTU	0.92	0.85
Maximum \| Measurement Input, Commodity Forward Price \| Valuation Technique, Option Pricing Model
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| $ / BTU	10.15	10.55
Weighted Average \| Measurement Input, Commodity Forward Price \| Valuation Technique, Option Pricing Model
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| $ / BTU	3.02	3.25
Long-term Power Commodity Contracts \| Valuation Technique, Discounted Cash Flow
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets \| $	$ 0	$ 0
Liabilities \| $	$ 330	$ 366
Long-term Power Commodity Contracts \| Minimum \| Measurement Input, Commodity Forward Price \| Valuation Technique, Discounted Cash Flow
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| $ / MWh	34.04	21.60
Long-term Power Commodity Contracts \| Maximum \| Measurement Input, Commodity Forward Price \| Valuation Technique, Discounted Cash Flow
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| $ / MWh	89.73	80.82
Long-term Power Commodity Contracts \| Weighted Average \| Measurement Input, Commodity Forward Price \| Valuation Technique, Discounted Cash Flow
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| $ / MWh	56.51	45.44
Heat Rate Call Option Commodity Contracts \| Valuation Technique, Option Pricing Model
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets \| $	$ 13	$ 9
Liabilities \| $	$ 3	$ 5
Heat Rate Call Option Commodity Contracts \| Minimum \| Measurement Input, Commodity Forward Price \| Valuation Technique, Option Pricing Model
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| $ / MWh	(29.26)	(19.30)
Heat Rate Call Option Commodity Contracts \| Maximum \| Measurement Input, Commodity Forward Price \| Valuation Technique, Option Pricing Model
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| $ / MWh	260.77	1,011.79
Heat Rate Call Option Commodity Contracts \| Weighted Average \| Measurement Input, Commodity Forward Price \| Valuation Technique, Option Pricing Model
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| $ / MWh	42.23	45.87
Other Financial Instruments \| Valuation Technique, Discounted Cash Flow
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets \| $	$ 7	$ 10
Liabilities \| $	$ 0	$ 0
Other Financial Instruments \| Minimum \| Measurement Input, Commodity Forward Price \| Valuation Technique, Discounted Cash Flow
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| MWh	60,047	59,425
Other Financial Instruments \| Maximum \| Measurement Input, Commodity Forward Price \| Valuation Technique, Discounted Cash Flow
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| MWh	120,094	118,850
Other Financial Instruments \| Weighted Average \| Measurement Input, Commodity Forward Price \| Valuation Technique, Discounted Cash Flow
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset/liability measurement input \| MWh	108,791	111,091

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Dec. 31, 2025
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Cash Flows from Operating Activities
Net loss	$ (171)	$ (33)	$ (13)
Adjustments to reconcile net loss to net cash provided by operating activities:
Equity in earnings of unconsolidated affiliates	(31)	(35)	(12)
Distributions from unconsolidated affiliates	32	34	30
Depreciation, amortization and accretion	682	627	526
Amortization of financing costs and debt discounts	15	14	13
Amortization of intangibles	187	182	185
Loss on debt extinguishment	8	5	6
Reduction in carrying amount of right-of-use assets	16	15	15
Impairment losses	0	0	12
Changes in deferred income taxes	(1)	1	(2)
Changes in derivative instruments and amortization of accumulated OCI	(13)	13	(2)
Changes in other working capital	(44)	(51)	(25)
Net Cash Provided by Operating Activities	680	772	733
Cash Flows from Investing Activities
Acquisitions, net of cash acquired	(324)	0	0
Acquisition of Drop Down Assets, net of cash acquired	(318)	(678)	(45)
Proceeds from transfer of assets	152	0	0
Capital expenditures	(319)	(287)	(212)
Payment for equipment deposit	0	0	(27)
Payment for equipment deposit and asset purchase from affiliate	(27)	0	(55)
Return of investments from unconsolidated affiliates	15	41	14
(Increase) decrease in note receivable — affiliate	(22)	184	(174)
Investments in unconsolidated affiliates	0	0	(28)
Other	18	15	4
Net Cash Used in Investing Activities	(825)	(725)	(523)
Cash Flows from Financing Activities
Contributions from noncontrolling interests, net of distributions	1,043	1,319	1,120
Contributions from (distributions to) CEG, net	81	174	(92)
Contributions from Clearway, Inc.	49	0	0
Proceeds from the issuance of Class C units	48	0	0
Payments of distributions	(358)	(334)	(311)
Pro-rata distributions to Clearway, Inc. and CEG	(44)	0	0
Tax-related distributions	0	(2)	(51)
Buyouts of noncontrolling interest and redeemable noncontrolling interest	(3)	(7)	(13)
Proceeds from the revolving credit facility	701	0	0
Payments for the revolving credit facility	(340)	0	0
Proceeds from issuance of long-term debt — external	518	466	563
Proceeds from issuance of long-term debt — affiliate	8	0	0
Payments for long-term debt — external	(1,461)	(1,966)	(1,349)
Payments for long-term debt — affiliate	(2)	(1)	(1)
Payments of debt issuance costs	(8)	(13)	(18)
Other	(2)	(1)	(3)
Net Cash Provided by (Used in) Financing Activities	230	(365)	(155)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	85	(318)	55
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	733	1,051	996
Cash, Cash Equivalents and Restricted Cash at End of Period	818	733	1,051
Supplemental Disclosure:
Interest paid, net of amount capitalized	$ (348)	$ (324)	$ (304)

Schedule I - Condensed Financial Statements - Footnotes (Details) $ in Millions	12 Months Ended
	Dec. 31, 2025 USD ($) state GW	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)
Condensed Cash Flow Statements, Captions [Line Items]
Power generation capacity, gigawatts (over)	12.9
Number of states \| state	27
Clearway Energy LLC
Condensed Cash Flow Statements, Captions [Line Items]
Cash distributions paid \| $	$ (358)	$ (334)	$ (311)
Clearway Energy LLC \| CEG
Condensed Cash Flow Statements, Captions [Line Items]
Ownership interest (as a percentage)	41.38%
Clearway Energy, Inc. \| Clearway Energy LLC
Condensed Cash Flow Statements, Captions [Line Items]
Ownership interest (as a percentage)	58.62%
Conventional Generation, Utility-Scale Solar, Distributed Solar, and Wind
Condensed Cash Flow Statements, Captions [Line Items]
Power generation capacity, gigawatts (over)	10.1
Generational Facilities and District Energy Systems
Condensed Cash Flow Statements, Captions [Line Items]
Power generation capacity, gigawatts (over)	2.8

Investments Accounted for by the Equity Method and Variable Interest Entities - Schedule of Maximum Exposure to Loss Limited to Equity method investments (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Schedule of Equity Method Investments [Line Items]
Investment Balance	$ 291	$ 309
Avenal
Schedule of Equity Method Investments [Line Items]
Economic Interest	50.00%
Investment Balance	$ 12
Desert Sunlight
Schedule of Equity Method Investments [Line Items]
Economic Interest	25.00%
Investment Balance	$ 212
Elkhorn Ridge
Schedule of Equity Method Investments [Line Items]
Economic Interest	66.70%
Investment Balance	$ (3)
Gen Conn
Schedule of Equity Method Investments [Line Items]
Economic Interest	50.00%
Investment Balance	$ 72
San Juan Mesa
Schedule of Equity Method Investments [Line Items]
Economic Interest	75.00%
Investment Balance	$ (2)

- Definition

This item represents the carrying amount on the entity's balance sheet of its investment in common stock of an equity method investee. This is not an indicator of the fair value of the investment, rather it is the initial cost adjusted for the entity's share of earnings and losses of the investee, adjusted for any distributions (dividends) and other than temporary impairment (OTTI) losses recognized.

+ References + Details

- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

+ References + Details

Property, Plant and Equipment (Tables)

12 Months Ended

Dec. 31, 2025

Property, Plant and Equipment [Abstract]

Schedule of Property, Plant and Equipment

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


	December 31, 2025		December 31, 2024		Depreciable Lives
	(In millions)
Facilities and equipment	$	15,095	$	13,302	3 - 40 Years
Land and improvements	644		537
Construction in progress (a) (b)	530		191
Total property, plant and equipment	16,269		14,030
Accumulated depreciation	(4,673)		(4,086)
Net property, plant and equipment	$	11,596	$	9,944

(b) As of December 31, 2025 and 2024, construction in progress included $12 million and $9 million, respectively, of accrued non-cash capital expenditures.

Investments Accounted for by the Equity Method and Variable Interest Entities - Schedule of Variable Interest Entities (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	$ 3,700	$ 3,318
Property, plant and equipment	11,596	9,944
Total assets	16,444	14,320
Total Liabilities	10,416	8,679
Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	1,031	755
Property, plant and equipment	7,894	5,985
Total assets	8,925	6,740
Total Liabilities	$ 2,594	$ 1,858

- Definition

Amount of asset recognized for present right to economic benefit.

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Amount of liability recognized for present obligation requiring transfer or otherwise providing economic benefit to others.

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Reference 29: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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-Paragraph 1B
-Subparagraph (SX 210.13-02(a)(5))
-Publisher FASB
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Reference 30: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 852
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 7
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481404/852-10-50-7

Reference 31: http://www.xbrl.org/2009/role/commonPracticeRef
-Topic 852
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 7
-Subparagraph (b)
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Reference 32: http://www.xbrl.org/2003/role/exampleRef
-Topic 280
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 30
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482810/280-10-50-30

+ Details

- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

+ References + Details

Cover - USD ($)

12 Months Ended

Dec. 31, 2025

Jan. 31, 2026

Jun. 30, 2025

Class of Stock [Line Items]

Document Type

10-K

Document Annual Report

true

Document Period End Date

Dec. 31, 2025

Current Fiscal Year End Date

--12-31

Document Transition Report

false

Entity File Number

333-203369

Entity Registrant Name

Clearway Energy LLC

Entity Incorporation, State or Country Code

Entity Tax Identification Number

32-0407370

Entity Address, Address Line One

300 Carnegie Center, Suite 300

Entity Address, City or Town

Princeton

Entity Address, State or Province

Entity Address, Postal Zip Code

08540

City Area Code

609

Local Phone Number

608-1525

Entity Well-known Seasoned Issuer

Entity Voluntary Filers

Yes

Entity Current Reporting Status

Yes

Entity Interactive Data Current

Yes

Entity Filer Category

Non-accelerated Filer

Entity Small Business

false

Entity Emerging Growth Company

false

Entity Shell Company

false

ICFR Auditor Attestation Flag

false

Document Financial Statement Error Correction

false

Entity Public Float

$ 0

Documents Incorporated by Reference

Documents Incorporated by Reference:

None.

Entity Central Index Key

0001637757

Amendment Flag

false

Document Fiscal Year Focus

2025

Document Fiscal Period Focus

Common Class A

Class of Stock [Line Items]

Entity Common Stock, Shares Outstanding

34,613,853

Common Class B

Class of Stock [Line Items]

Entity Common Stock, Shares Outstanding

42,738,750

Common Class C

Class of Stock [Line Items]

Entity Common Stock, Shares Outstanding

86,290,173

Common Class D

Class of Stock [Line Items]

Entity Common Stock, Shares Outstanding

41,576,142

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2025

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 GAAP. The FASB ASC is the source of authoritative 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 GAAP for SEC registrants.

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

Cash, Cash Equivalents and Restricted Cash

Cash and cash equivalents include highly liquid investments with an original maturity of three months or less at the time of purchase. Cash and cash equivalents held at subsidiary facilities was $194 million as of both December 31, 2025 and 2024.


	December 31,
	2025		2024
	(In millions)
Cash and cash equivalents	$	231	$	332
Restricted cash	587		401
Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows	$	818	$	733

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

As of December 31, 2025, these restricted funds were comprised of $146 million designated to fund operating expenses, $99 million designated for current debt service payments and $85 million restricted for reserves, including debt service, performance obligations and other reserves as well as capital expenditures. The remaining $257 million is held in distribution reserve accounts, of which $174 million relates to transferable ITCs for the Rosamond South I solar and BESS facility that were received on behalf of the tax equity investor in Rosie South TE Holdco LLC and subsequently distributed to the tax equity investor in January 2026.

As of December 31, 2024, these restricted funds were comprised of $184 million designated to fund operating expenses, $37 million designated for current debt service payments and $102 million restricted for reserves, including debt service, performance obligations and other reserves as well as capital expenditures. The remaining $78 million was held in distribution reserve accounts.

Supplemental Cash Flow Information

The following table provides a disaggregation of the amounts classified as Acquisition of Drop Down Assets, net of cash acquired, shown in the consolidated statements of cash flows:


	Year ended December 31,
	2025		2024		2023
	(In millions)
Cash paid to acquire Drop Down Assets	$	(329)	$	(680)	$	(173)
Cash acquired from the acquisition of Drop Down Assets	11		2		128
Acquisition of Drop Down Assets, net of cash acquired	$	(318)	$	(678)	$	(45)

Accounts Receivable — Trade and Allowance for Credit Losses

Accounts receivable — trade are reported on the consolidated balance sheet at the invoiced amount adjusted for any write-offs and the allowance for credit losses. The majority of the Company’s customers typically receive invoices monthly with payment due within 30 days. The allowance for credit losses is reviewed periodically based on amounts past due and their significance. The allowance for credit losses was immaterial as of December 31, 2025 and 2024.

Inventory

Inventory consists of spare parts and is valued at weighted average cost, unless evidence indicates that the weighted average cost will not be recovered with a normal profit in the ordinary course of business. Inventory is removed when used for repairs, maintenance or capital projects.

Property, Plant and Equipment

Property, plant and equipment are stated at cost, however, impairment adjustments are recorded whenever events or changes in circumstances indicate that their carrying amounts may not be recoverable. Significant additions or improvements extending asset lives are capitalized as incurred, while repairs and maintenance that do not improve or extend the life of the respective asset are charged to expense as incurred. Depreciation is computed using the straight-line method over the estimated useful lives. Certain assets and their related accumulated depreciation amounts are adjusted for asset retirements and disposals with the resulting gain or loss included in cost of operations in the consolidated statements of operations. For further discussion of the Company’s property, plant and equipment refer to Note 4, Property, Plant and Equipment.

Interest incurred on funds borrowed to finance capital projects is capitalized until the project under construction is ready for its intended use. The amount of interest capitalized for the years ended December 31, 2025, 2024 and 2023 was $51 million, $28 million and $36 million, respectively.

Construction in-progress represents cumulative construction costs, including the costs incurred for the purchase of major equipment and engineering costs and capitalized interest. Once the project achieves commercial operation, the Company reclassifies the amounts recorded in construction in progress to facilities and equipment.

Asset Impairments

Long-lived assets that are held and used are reviewed for impairment whenever events or changes in circumstances indicate their carrying amounts may not be recoverable. Such reviews are performed in accordance with ASC 360, Property, Plant and Equipment. An impairment loss is indicated if the total future estimated undiscounted cash flows expected from an asset are less than its carrying amount. An impairment charge is measured as the excess of an asset’s carrying amount over its 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 appraisals, sales prices of similar assets and present value techniques. For further discussion of the Company’s long-lived asset impairments, refer to Note 9, Asset Impairments.

Investments accounted for by the equity method are reviewed for impairment in accordance with ASC 323, Investments-Equity Method and Joint Ventures, 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.

Debt Issuance Costs

Debt issuance costs are capitalized and amortized as interest expense on a basis which approximates the effective interest method over the term of the related debt. Debt issuance costs related to the long-term debt are presented as a direct deduction from the carrying amount of the related debt. Debt issuance costs related to the senior secured revolving credit facility line of credit are recorded as a non-current asset on the consolidated balance sheet and are amortized over the term of the credit facility.

Intangible Assets

Intangible assets represent contractual rights held by the Company. The Company recognizes specifically identifiable intangible assets, including PPAs, leasehold rights, emission allowances, RECs and development rights when specific rights and contracts are acquired. These intangible assets are amortized primarily on a straight-line basis. For further discussion of the Company’s intangible assets, refer to Note 8, Intangible Assets.

Income Taxes

The Company is classified as a partnership for federal and state income tax purposes. Therefore, federal and most state income taxes are assessed at the partner level. The franchise tax imposed by the state of Texas, however, is being assessed at the level of certain operating subsidiaries of the Company, and therefore reflected as an income tax expense or benefit of the Company.

For the year ended December 31, 2025, the Company recorded a deferred tax benefit of $1 million, which resulted in a cumulative deferred tax liability of $2 million with respect to future years. For the year ended December 31, 2024, the Company recorded a deferred tax expense of $1 million, which resulted in a cumulative deferred tax liability of $3 million with respect to future years.

Revenue Recognition

Revenue from Contracts with Customers

The Company applies the guidance in ASC 606, Revenue from Contracts with Customers, or Topic 606, when recognizing revenue associated with its contracts with customers. The Company’s policies with respect to its various revenue streams are detailed below. In general, the Company 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.

Flexible Generation Segment Revenues

The majority of the facilities in the Flexible Generation segment commenced merchant operations during 2023 following the expiration of the PPAs. These facilities generate revenues from selling electricity and/or RA to the CAISO and to public utility and load serving entities, as the power is delivered at the interconnection point.

Power Purchase Agreements, or PPAs

The majority of the Company’s revenues are obtained through PPAs or similar contractual agreements. Energy, capacity and, where applicable, renewable attributes, from the majority of the Company’s renewable energy assets and certain facilities in the Flexible Generation segment are sold through long-term PPAs and tolling agreements to a single counterparty, which is often a utility or commercial customer. Certain revenue agreements also provide for the sale of BESS capacity. As discussed above, the majority of the facilities in the Flexible Generation segment commenced merchant operations during 2023 following the expiration of the PPAs. The majority of these PPAs are accounted for as operating leases as the Company retained its historical lease assessments and classification upon adoption of ASC 842, Leases. ASC 842 requires the minimum lease payments received to be amortized over the term of the lease and contingent rentals are recorded when the achievement of the contingency becomes probable. The Company’s BESS arrangements include variable payments not based on an index or rate and sales-type lease treatment would result in a loss at lease commencement. As a result, the Company accounts for these arrangements as operating leases under ASC 842. Judgment is required by management in determining the economic life of each generating facility, in evaluating whether certain lease provisions constitute minimum payments or represent contingent rent and other factors in determining whether a contract contains a lease and whether the lease is an operating lease or finance lease.

Certain of these PPAs have no minimum lease payments and all of the lease revenue under these PPAs is recorded as contingent rent on an actual basis when the electricity is delivered. The contingent lease revenue recognized in the years ended December 31, 2025, 2024 and 2023 was $797 million, $831 million and $780 million, respectively. See Note 15, Leases, for additional information related to the Company’s PPAs accounted for as leases.

Renewable Energy Credits, or RECs

Renewable energy credits, or RECs, are usually sold through long-term PPAs or through REC contracts with counterparties. Revenue from the sale of self-generated RECs is recognized when the related energy is generated and simultaneously delivered even in cases where there is a certification lag as it has been deemed to be perfunctory.

In a bundled contract to sell energy, capacity and/or self-generated RECs, all performance obligations are deemed to be delivered at the same time and hence, timing of recognition of revenue for all performance obligations is the same and occurs over time. In such cases, it is unnecessary to allocate transaction price to multiple performance obligations.

Disaggregated Revenues

The following tables represent the Company’s disaggregation of revenue from contracts with customers, along with the reportable segment for each category:


	Year ended December 31, 2025
(In millions)	Flexible Generation		Renewables & Storage		Total
Energy revenue (a)	$	30	$	1,166	$	1,196
Capacity revenue (a)	269		100		369
Other revenues	4		72		76
Contract amortization	(18)		(171)		(189)
Mark-to-market for economic hedges	6		(29)		(23)
Total operating revenues	291		1,138		1,429
Less: Contract amortization	18		171		189
Less: Mark-to-market for economic hedges	(6)		29		23
Less: Lease revenue	(115)		(846)		(961)

Total revenue from contracts with customers	$	188	$	492	$	680

(a) See Note 15, Leases, for the amounts of energy and capacity revenues that relate to leases and are accounted for under ASC 842.


	Year ended December 31, 2024
(In millions)	Flexible Generation		Renewables & Storage		Total
Energy revenue (a)	$	84	$	1,089	$	1,173
Capacity revenue (a)	262		65		327
Other revenues (a)	5		85		90
Contract amortization	(18)		(166)		(184)
Mark-to-market for economic hedges	9		(44)		(35)
Total operating revenues	342		1,029		1,371
Less: Contract amortization	18		166		184
Less: Mark-to-market for economic hedges	(9)		44		35
Less: Lease revenue	(113)		(860)		(973)
Total revenue from contracts with customers	$	238	$	379	$	617

(a) See Note 15, Leases, for the amounts of energy, capacity and other revenues that relate to leases and are accounted for under ASC 842.


	Year ended December 31, 2023
(In millions)	Flexible Generation		Renewables & Storage		Total
Energy revenue (a)	$	81	$	942	$	1,023
Capacity revenue (a)	336		23		359
Other revenues	28		71		99
Contract amortization	(20)		(166)		(186)
Mark-to-market for economic hedges	(5)		24		19
Total operating revenues	420		894		1,314
Less: Contract amortization	20		166		186
Less: Mark-to-market for economic hedges	5		(24)		(19)
Less: Lease revenue	(274)		(780)		(1,054)
Total revenue from contracts with customers	$	171	$	256	$	427

(a) See Note 15, Leases, for the amounts of energy and capacity revenues that relate to leases and are accounted for under ASC 842.

Contract Amortization

Assets and liabilities recognized from power sales agreements assumed through acquisitions relating to the sale of electric capacity and energy in future periods arising from differences in contract and market prices are amortized to revenue over the term of each underlying contract based on actual generation and/or contracted volumes or on a straight-line basis, where applicable.

Contract Balances

The following table reflects the contract assets included on the Company’s consolidated balance sheets:


(In millions)	December 31, 2025		December 31, 2024
Accounts receivable, net - Contracts with customers	$	76	$	75
Accounts receivable, net - Leases	86		89
Total accounts receivable, net	$	162	$	164

Derivative Financial Instruments

The Company accounts for derivative financial instruments under ASC 815, Derivatives and Hedging, or ASC 815, which requires the Company to record all derivatives on the balance sheet at fair value unless they qualify for a NPNS exception. Changes in the fair value of non-hedge derivatives are immediately recognized in earnings. Changes in the fair value of derivatives accounted for as hedges, if elected for hedge accounting, are deferred and recorded as a component of accumulated OCI/OCL until the hedged transactions occur and are recognized in earnings.

The Company’s primary derivative financial instruments are interest rate instruments used to mitigate variability in earnings due to fluctuations in interest rates and energy-related instruments used to mitigate variability in earnings due to fluctuations in power market prices or natural gas market prices. Certain derivative contracts contain provisions providing the counterparties a lien on specific assets as collateral. On an ongoing basis, the Company qualitatively assesses the effectiveness of its derivatives that are designated as hedges for accounting purposes in order to determine that each derivative continues to be highly effective in offsetting changes in cash flows of hedged items. If necessary, the Company will perform an analysis to measure the statistical correlation between the derivative and the associated hedged item to determine the effectiveness of such a contract designated as a hedge. The Company will discontinue hedge accounting if it is determined that the hedge is no longer effective. In this case, the gain or loss previously deferred in accumulated OCI/OCL would be frozen until the underlying hedged item is delivered unless the transaction being hedged is no longer probable of occurring in which case the amount in accumulated OCI/OCL would be immediately reclassified into earnings. If the derivative financial instrument is terminated, the effective portion of this derivative deferred in accumulated OCI/OCL will be frozen until the underlying hedged item is delivered.

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 financial 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.

Cash flows from derivative financial instruments, including derivatives designated as cash flow hedges and derivatives not designated as cash flow hedges, are classified as operating activities in the consolidated statements of cash flows.

Concentrations of Credit Risk

Financial instruments which potentially subject the Company to concentrations of credit risk consist primarily of accounts receivable — trade and derivative financial instruments, which are concentrated within entities engaged in the energy and financial industries. These industry concentrations may impact the 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. In addition, many of the Company’s facilities have only one customer. See Note 6, Fair Value of Financial Instruments, for a further discussion of derivative concentrations and Note 12, Segment Reporting, for concentration of counterparties.

Fair Value of Financial Instruments

The carrying amount of cash and cash equivalents, restricted cash, accounts receivable — trade, accounts receivable — affiliates accounts payable — trade, accounts payable — affiliates and accrued expenses and other current liabilities approximate fair value because of the short-term maturity of these instruments. See Note 6, Fair Value of Financial Instruments, for a further discussion of fair value of financial instruments.

Asset Retirement Obligations

Asset retirement obligations, or AROs, are accounted for 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, other than when an ARO is assumed in an acquisition of the related long-lived asset, the asset retirement cost is capitalized 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. The Company’s AROs are primarily related to the future dismantlement of equipment on leased property and environmental obligations related to site closures and fuel storage facilities. The Company records AROs as part of other non-current liabilities on its consolidated balance sheet.

The following table represents the balance of AROs, along with the related activity:


(In millions)
Balance as of December 31, 2023	$	239
Revisions in estimated cash flows	(1)
Liabilities incurred	14
Liabilities settled	(2)
Accretion expense	16
Balance as of December 31, 2024	266
Revisions in estimated cash flows	7
Liabilities incurred	38
Liabilities settled	(5)
Accretion expense	18
Balance as of December 31, 2025	$	324

Guarantees

The Company enters into various contracts that include indemnification and guarantee provisions as a routine part of its business activities. Examples of these contracts include operation and maintenance agreements, service agreements, commercial sales arrangements 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. Because many of the guarantees and indemnities the Company 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 agreed upon in the contracts mentioned above. For those guarantees and indemnities that do not limit the liability exposure, the Company may not be able to estimate what the liability would be, until a claim is made for payment or performance, due to the contingent nature of these contracts.

Investments Accounted for by the Equity Method

The Company has investments in various energy facilities accounted for by the equity method, several of which are VIEs, where the Company is not a primary beneficiary, as described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. The equity method of accounting is applied to these investments in affiliates because the ownership structure prevents the Company from exercising a controlling influence over the operating and financial policies of the facilities. Under this method, equity in pre-tax income or losses of the investments is 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.

Sale-Leaseback Arrangements

The Company is party to sale-leaseback arrangements that provide for the sale of certain assets to a third-party and simultaneous leaseback to the Company. In accordance with ASC 842-40, Sale-Leaseback Transactions, if the seller-lessee retains, through the leaseback, substantially all of the benefits and risks incident to the ownership of the property sold, the sale-leaseback transaction is accounted for as a financing arrangement. An example of this type of continuing involvement would include an option to repurchase the assets or the buyer-lessor having the option to sell the assets back to the Company. This provision is included in most of the Company’s sale-leaseback arrangements. As such, the Company accounts for these arrangements as financings.

Under the financing method, the Company does not recognize as income any of the sale proceeds received from the lessor that contractually constitutes payment to acquire the assets subject to these arrangements. Instead, the sale proceeds received are accounted for as financing obligations and leaseback payments made by the Company are allocated between interest expense and a reduction to the financing obligation. Interest on the financing obligation is calculated using the Company’s incremental borrowing rate at the inception of the arrangement on the outstanding financing obligation. Judgment is required to determine the appropriate borrowing rate for the arrangement and in determining any gain or loss on the transaction that would be recorded either at the end of or over the lease term.

Asset Acquisitions

The Company accounts for its acquisitions in accordance with ASC 805, Business Combinations, or ASC 805. For third-party acquisitions, ASC 805 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. No goodwill is recognized, and excess purchase price or negative goodwill are allocated to the acquired assets on a relative fair value basis. For acquisitions that relate to entities under common control, the difference between the cash paid and historical value of the entities’ equity is recorded as a distribution/contribution from/to CEG with the offset to contributed capital.

Tax Equity Arrangements

Certain portions of the Company’s redeemable noncontrolling interest in subsidiaries and noncontrolling interest represent third-party interests in the net assets under tax equity arrangements, which are consolidated by the Company, that have been entered into to finance the cost of facilities eligible for certain tax credits and benefits. The Company has determined that the provisions in the contractual agreements of these redeemable noncontrolling interests and noncontrolling interests represent substantive profit sharing arrangements. Further, the Company has determined that the appropriate methodology for calculating the redeemable noncontrolling interest and noncontrolling interest that reflects the substantive profit sharing arrangements is a balance sheet approach utilizing the hypothetical liquidation at book value, or HLBV, method. Under the HLBV method, the amounts reported as redeemable noncontrolling interest and noncontrolling interest represent the amounts the investors 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 determined in accordance with GAAP. The investors’ interests in the results of operations of the funding structures are determined as the difference in redeemable noncontrolling interest and noncontrolling interest at the start and end of each reporting period, after taking into account any capital transactions between the structures and the funds’ investors. The calculations utilized to apply the HLBV method include estimated calculations of taxable income or losses for each reporting period. In addition, in certain circumstances, the Company and its partners in the tax equity arrangements agree that certain tax benefits are to be utilized outside of the tax equity arrangements, which may result in differences in the amount an investor would hypothetically receive at the initial balance sheet date calculated strictly in accordance with related contractual agreements. These differences are recognized in the consolidated statements of operations using a systematic and rational method over the period during which the investor is expected to achieve its target return.

Redeemable Noncontrolling Interest

To the extent that a third party has the right to redeem their interests for cash or other assets, the Company has included the noncontrolling interest attributable to the third party as a component of temporary equity in the mezzanine section of the consolidated balance sheet. In 2025, the Company entered into new tax equity arrangements that provide third parties with the right to redeem their interests in the partnerships for cash or other assets at a point in time, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. The following table reflects the changes in the Company’s redeemable noncontrolling interest balance:


	(In millions)
Balance at December 31, 2023	$	1
Cash distributions to redeemable noncontrolling interests	(2)
Comprehensive income attributable to redeemable noncontrolling interests	13
Repurchase of redeemable noncontrolling interest	(12)
Balance at December 31, 2024	—
Cash contributions to redeemable noncontrolling interests, net of distributions	335
Non-cash distributions to redeemable noncontrolling interests	(12)
Comprehensive loss attributable to redeemable noncontrolling interests	(220)
Balance at December 31, 2025	$	103

Use of Estimates

The preparation of consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions. These estimates and assumptions impact the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities as of the date of the consolidated financial statements. They also impact the reported amounts of net earnings during the reporting periods. Actual results could be different 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, uncollectible accounts, AROs, acquisition accounting, fair value of financial instruments and legal costs incurred in connection with recorded loss contingencies, among others. In addition, estimates are used to test long-lived assets 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.

Recent Accounting Standards Not Yet Adopted

In December 2025, the FASB issued ASU No 2025-10, Government Grants - (Topic 832): Accounting for Government Grants Received by Business Entities. The amendment establishes the accounting guidance for governmental grants received by a business entity. This guidance is effective for annual reporting periods beginning after December 15, 2028 and interim reporting periods within the annual reporting period. The amendment may be applied on a modified prospective approach, a modified retrospective approach or retrospectively. Early adoption is permitted in both interim and annual reporting periods. As of December 31, 2025, the Company has not elected to early adopt the standard and is evaluating the effect of the new guidance on its consolidated financial statements.

In September 2025, the FASB issued ASU No. 2025-06, Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Targeted Improvements to the Accounting for Internal-Use Software. The amendment clarifies when software costs should be capitalized and requires certain disclosures for all capitalized internal-use software costs. This guidance may be applied prospectively, retrospectively or on a modified retrospective basis and is effective for annual reporting periods in fiscal years beginning after December 15, 2027. The Company intends to early adopt ASU 2025-06 prospectively, effective January 1, 2026. The adoption is not expected to have an impact on the Company’s financial statements.

In September 2025, the FASB issued ASU No. 2025-07, Derivatives and Hedging (Topic 815) and Revenue from Contracts with Customers (Topic 606): Derivatives Scope Refinements and Scope Clarification for Share-Based Noncash Consideration from a Customer in a Revenue Contract. The amendment expands the derivative scope exceptions and clarifies when an entity should apply the guidance in ASC 606, Revenue from Contracts with Customers, to contracts with share-based noncash consideration from a customer for the transfer of goods or services. This guidance may be applied either prospectively or on a modified retrospective basis and is effective for annual reporting periods in fiscal years beginning after December 15, 2026. The Company intends to early adopt ASU 2025-07 prospectively, effective January 1, 2026. The adoption is not expected to have an impact on the Company’s financial statements.

In November 2024, the FASB issued ASU No 2024-03, Income Statement - Reporting Comprehensive Income-Expense Disaggregation Disclosures (Subtopic 220-40). The amendment requires certain expenses presented on the face of the income statement to be disaggregated in the notes to the financial statements. This guidance is effective for annual reporting periods beginning after December 15, 2026 and interim periods within annual reporting periods beginning after December 15, 2027. The amendments may be applied either prospectively to financial statements issued for reporting periods after the effective date of this ASU or retrospectively to all prior periods presented in the financial statements. As of December 31, 2025, the Company has not elected to early adopt the standard and is evaluating the effect of the new guidance on its consolidated financial statements.

Revision of Previously Issued Unaudited Financial Information (Unaudited)

12 Months Ended

Dec. 31, 2025

Quarterly Financial Information Disclosure [Abstract]

Revision of Previously Issued Unaudited Financial Information (Unaudited)

During the fourth quarter of 2025, the Company’s management identified errors related to certain calculations of hypothetical liquidation at book value (HLBV) accounting used to allocate net income (loss) to the Company’s redeemable noncontrolling interests and noncontrolling interests in tax equity partnerships in each of the quarters ended March 31, 2025, June 30, 2025 and September 30, 2025. The Company evaluated the materiality of the errors in accordance with Staff Accounting Bulletins No. 99 and No. 108 of the SEC and concluded that the errors were immaterial to all previously reported periods and did not require restatement of any previously issued financial statements.

The corrections had no impact on the Company’s consolidated net income (loss) or its consolidated statements of cash flows contained in the Company’s previously issued Quarterly Reports on Form 10-Q for the quarters ended March 31, 2025, June 30, 2025 and September 30, 2025. The Company will revise prior period financial information, including the corresponding notes to the financial statements, related to the errors contained in its previously issued Quarterly Reports on Form 10-Q for the quarters ended March 31, 2025, June 30, 2025 and September 30, 2025, the next time the respective periods are presented.

A summary of the corrections to the impacted financial statement line items is presented below:


	Three months ended March 31, 2025
(in millions)	As Previously Reported		Adjustments		As Revised
	(Unaudited)
Consolidated Statement of Operations
Net loss attributable to noncontrolling interests	$	(111)	$	12	$	(99)
Net income (loss) attributable to Clearway Energy LLC	$	7	$	(12)	$	(5)
Consolidated Statement of Comprehensive Income (Loss)
Comprehensive loss attributable to noncontrolling interests	$	(113)	$	12	$	(101)
Comprehensive income (loss) attributable to Clearway Energy LLC	$	3	$	(12)	$	(9)
Consolidated Balance Sheet (As of March 31, 2025)

Retained earnings	$	814	$	(12)	$	802
Noncontrolling interest	3,851		12		3,863
Total Members’ Equity	$	5,479	$	—	$	5,479
Consolidated Statements of Members’ Equity
Retained Earnings:
Net income (loss)	$	7	$	(12)	$	(5)
Retained Earnings at March 31, 2025	$	814	$	(12)	$	802
Noncontrolling Interest:
Net loss	$	(111)	$	12	$	(99)
Noncontrolling Interest at March 31, 2025	$	3,851	$	12	$	3,863


	Three months ended June 30, 2025						Six months ended June 30, 2025
(in millions)	As Previously Reported		Adjustments		As Revised		As Previously Reported		Adjustments		As Revised
	(Unaudited)						(Unaudited)
Consolidated Statement of Operations
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	$	(50)	$	5	$	(45)	$	(161)	$	17	$	(144)
Net income attributable to Clearway Energy LLC	$	69	$	(5)	$	64	$	76	$	(17)	$	59
Consolidated Statement of Comprehensive Income
Comprehensive loss attributable to noncontrolling interests and redeemable noncontrolling interests	$	(51)	$	5	$	(46)	$	(164)	$	17	$	(147)
Comprehensive income attributable to Clearway Energy LLC	$	53	$	(5)	$	48	$	56	$	(17)	$	39
Consolidated Balance Sheet (As of June 30, 2025)
Redeemable noncontrolling interest in subsidiaries	$	38	$	7	$	45
Retained earnings	778		(17)		761
Noncontrolling interest	4,152		10		4,162
Total Members’ Equity	$	5,575	$	(7)	$	5,568
Consolidated Statements of Members’ Equity
Retained Earnings:
Net income	$	69	$	(5)	$	64
Retained Earnings at June 30, 2025	$	778	$	(17)	$	761
Noncontrolling Interest:
Net loss	$	(37)	$	(2)	$	(39)
Noncontrolling Interest at June 30, 2025	$	4,152	$	10	$	4,162


	Three months ended September 30, 2025						Nine months ended September 30, 2025
(in millions)	As Previously Reported		Adjustments		As Revised		As Previously Reported		Adjustments		As Revised
	(Unaudited)						(Unaudited)
Consolidated Statement of Operations
Net loss attributable to noncontrolling interests and redeemable noncontrolling interests	$	(322)	$	6	$	(316)	$	(483)	$	23	$	(460)
Net income attributable to Clearway Energy LLC	$	351	$	(6)	$	345	$	427	$	(23)	$	404
Consolidated Statement of Comprehensive Income
Comprehensive loss attributable to noncontrolling interests and redeemable noncontrolling interests	$	(322)	$	6	$	(316)	$	(486)	$	23	$	(463)
Comprehensive income attributable to Clearway Energy LLC	$	346	$	(6)	$	340	$	402	$	(23)	$	379
Consolidated Balance Sheet (As of September 30, 2025)
Redeemable noncontrolling interest in subsidiaries	$	74	$	30	$	104
Retained earnings	1,039		(23)		1,016
Noncontrolling interest	4,156		(7)		4,149
Total Members’ Equity	$	5,697	$	(30)	$	5,667
Consolidated Statements of Members’ Equity
Retained Earnings:
Net income	$	351	$	(6)	$	345
Retained Earnings at September 30, 2025	$	1,039	$	(23)	$	1,016
Noncontrolling Interest:
Net loss	$	(137)	$	(17)	$	(154)
Noncontrolling Interest at September 30, 2025	$	4,156	$	(7)	$	4,149