Cover
Cover - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Jan. 31, 2024 | Jun. 30, 2023 | |
Class of Stock | |||
Document Type | 10-K | ||
Document Annual Report | true | ||
Document Period End Date | Dec. 31, 2023 | ||
Current Fiscal Year End Date | --12-31 | ||
Document Transition Report | false | ||
Entity File Number | 001-36002 | ||
Entity Registrant Name | Clearway Energy, Inc. | ||
Entity Incorporation, State or Country Code | DE | ||
Entity Tax Identification Number | 46-1777204 | ||
Entity Address, Address Line One | 300 Carnegie Center, Suite 300 | ||
Entity Address, City or Town | Princeton | ||
Entity Address, State or Province | NJ | ||
Entity Address, Postal Zip Code | 08540 | ||
City Area Code | 609 | ||
Local Phone Number | 608-1525 | ||
Entity Well-known Seasoned Issuer | Yes | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Interactive Data Current | Yes | ||
Entity Filer Category | Large Accelerated Filer | ||
Entity Small Business | false | ||
Entity Emerging Growth Company | false | ||
Entity Shell Company | false | ||
ICFR Auditor Attestation Flag | true | ||
Document Financial Statement Error Correction | false | ||
Entity Public Float | $ 2,540 | ||
Documents Incorporated by Reference | Documents Incorporated by Reference: Portions of the Registrant’s Definitive Proxy Statement relating to its 2024 Annual Meeting of Stockholders are incorporated by reference into Part III of this Annual Report on Form 10-K | ||
Entity Central Index Key | 0001567683 | ||
Amendment Flag | false | ||
Document Fiscal Year Focus | 2023 | ||
Document Fiscal Period Focus | FY | ||
Common Class A | |||
Class of Stock | |||
Title of 12(b) Security | Class A Common Stock, par value $0.01 | ||
Trading Symbol | CWEN.A | ||
Security Exchange Name | NYSE | ||
Entity Common Stock, Shares Outstanding | 34,613,853 | ||
Common Class B | |||
Class of Stock | |||
Entity Common Stock, Shares Outstanding | 42,738,750 | ||
Common Class C | |||
Class of Stock | |||
Title of 12(b) Security | Class C Common Stock, par value $0.01 | ||
Trading Symbol | CWEN | ||
Security Exchange Name | NYSE | ||
Entity Common Stock, Shares Outstanding | 82,391,441 | ||
Common Class D | |||
Class of Stock | |||
Entity Common Stock, Shares Outstanding | 42,336,750 |
Audit Information
Audit Information | 12 Months Ended |
Dec. 31, 2023 | |
Audit Information [Abstract] | |
Auditor Name | Ernst & Young LLP |
Auditor Firm ID | 42 |
Auditor Location | Philadelphia, Pennsylvania |
CONSOLIDATED STATEMENTS OF INCO
CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Operating Revenues | |||
Total operating revenues | $ 1,314 | $ 1,190 | $ 1,286 |
Operating Costs and Expenses | |||
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 473 | 435 | 451 |
Depreciation, amortization and accretion | 526 | 512 | 509 |
Impairment losses | 12 | 16 | 6 |
General and administrative | 36 | 40 | 40 |
Transaction and integration costs | 4 | 7 | 7 |
Development costs | 0 | 2 | 6 |
Total operating costs and expenses | 1,051 | 1,012 | 1,019 |
Gain on sale of business | 0 | 1,292 | 0 |
Operating income (loss) | 263 | 1,470 | 267 |
Other Income (Expense) | |||
Equity in earnings of unconsolidated affiliates | 12 | 29 | 32 |
Other income, net | 52 | 17 | 3 |
Loss on debt extinguishment | (6) | (2) | (53) |
Interest expense | (337) | (232) | (312) |
Total other expense, net | (279) | (188) | (330) |
(Loss) Income Before Income Taxes | (16) | 1,282 | (63) |
Income tax (benefit) expense | (2) | 222 | 12 |
Net (Loss) Income | (14) | 1,060 | (75) |
Less: Net (loss) income attributable to noncontrolling interests and redeemable noncontrolling interests | (93) | 478 | (126) |
Net Income (Loss) Attributable to Clearway Energy, Inc. | $ 79 | $ 582 | $ 51 |
Earnings Per Share Attributable to Clearway Energy, Inc. Class A and Class C Common Stockholders | |||
Weighted average number of common shares outstanding - diluted (in shares) | 35 | 35 | 35 |
Earnings per weighted average common share - basic (in dollars per share) | $ 0.67 | $ 4.99 | $ 0.44 |
Earnings per weighted average common share - diluted (in dollars per share) | $ 0.67 | $ 4.99 | $ 0.44 |
Common Class A | |||
Other Income (Expense) | |||
Net Income (Loss) Attributable to Clearway Energy, Inc. | $ 23 | $ 172 | $ 15 |
Earnings Per Share Attributable to Clearway Energy, Inc. Class A and Class C Common Stockholders | |||
Weighted average number of shares outstanding - basic (in shares) | 35 | 35 | 35 |
Weighted average number of common shares outstanding - diluted (in shares) | 35 | 35 | 35 |
Earnings per weighted average common share - basic (in dollars per share) | $ 0.67 | $ 4.99 | $ 0.44 |
Earnings per weighted average common share - diluted (in dollars per share) | 0.67 | 4.99 | 0.44 |
Dividends per common share (in usd per share) | $ 1.54 | $ 1.43 | $ 1.33 |
Common Class C | |||
Other Income (Expense) | |||
Net Income (Loss) Attributable to Clearway Energy, Inc. | $ 56 | $ 410 | $ 36 |
Earnings Per Share Attributable to Clearway Energy, Inc. Class A and Class C Common Stockholders | |||
Weighted average number of shares outstanding - basic (in shares) | 82 | 82 | 82 |
Weighted average number of common shares outstanding - diluted (in shares) | 82 | 82 | 82 |
Earnings per weighted average common share - basic (in dollars per share) | $ 0.67 | $ 4.99 | $ 0.44 |
Earnings per weighted average common share - diluted (in dollars per share) | 0.67 | 4.99 | 0.44 |
Dividends per common share (in usd per share) | $ 1.54 | $ 1.43 | $ 1.33 |
CONSOLIDATED STATEMENTS OF COMP
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Statement of Comprehensive Income [Abstract] | |||
Net (Loss) Income | $ (14) | $ 1,060 | $ (75) |
Other Comprehensive (Loss) Income, net of tax | |||
Unrealized (loss) gain on derivatives and changes in accumulated OCI/OCL, net of income tax (benefit) expense of $(1), $5 and $(3) | (6) | 28 | 19 |
Other comprehensive (loss) income | (6) | 28 | 19 |
Comprehensive (Loss) Income | (20) | 1,088 | (56) |
Less: Comprehensive (loss) income attributable to noncontrolling interests and redeemable noncontrolling interests | (97) | 495 | (115) |
Comprehensive Income Attributable to Clearway Energy, Inc. | $ 77 | $ 593 | $ 59 |
CONSOLIDATED STATEMENTS OF CO_2
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Statement of Comprehensive Income [Abstract] | |||
Unrealized (loss) gain on derivatives, income tax expense | $ (1) | $ 5 | $ (3) |
CONSOLIDATED BALANCE SHEETS
CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Current Assets | ||
Cash and cash equivalents | $ 535 | $ 657 |
Restricted cash | 516 | 339 |
Inventory | 55 | 47 |
Derivative instruments | 41 | 26 |
Prepayments and other current assets | 68 | 54 |
Total current assets | 1,560 | 1,276 |
Property, plant and equipment, net | 9,526 | 7,421 |
Other Assets | ||
Equity investments in affiliates | 360 | 364 |
Intangible assets for power purchase agreements, net | 2,303 | 2,488 |
Other intangible assets, net | 71 | 77 |
Derivative instruments | 82 | 63 |
Right-of-use assets, net | 597 | 527 |
Other non-current assets | 202 | 96 |
Total other assets | 3,615 | 3,615 |
Total Assets | 14,701 | 12,312 |
Current Liabilities | ||
Current portion of long-term debt | 558 | 322 |
Accounts payable — trade | 130 | 55 |
Derivative instruments | 51 | 50 |
Accrued interest expense | 57 | 54 |
Accrued expenses and other current liabilities | 79 | 114 |
Total current liabilities | 906 | 617 |
Other Liabilities | ||
Long-term debt | 7,479 | 6,491 |
Deferred income taxes | 127 | 119 |
Derivative instruments | 281 | 303 |
Long-term lease liabilities | 627 | 548 |
Other non-current liabilities | 286 | 201 |
Total other liabilities | 8,800 | 7,662 |
Total Liabilities | 9,706 | 8,279 |
Redeemable noncontrolling interest in subsidiaries | 1 | 7 |
Commitments and Contingencies | ||
Stockholders’ Equity | ||
Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued | 0 | 0 |
Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 202,080,794 shares issued and outstanding (Class A 34,613,853, Class B 42,738,750, Class C 82,391,441, Class D 42,336,750) at December 31, 2023 and 201,972,813 shares issued and outstanding (Class A 34,613,853, Class B 42,738,750, Class C 82,283,460, Class D 42,336,750) at December 31, 2022 | 1 | 1 |
Additional paid-in capital | 1,732 | 1,761 |
Retained earnings | 361 | 463 |
Accumulated other comprehensive income | 7 | 9 |
Noncontrolling interest | 2,893 | 1,792 |
Total Stockholders’ Equity | 4,994 | 4,026 |
Total Liabilities and Stockholders’ Equity | 14,701 | 12,312 |
Nonrelated Party | ||
Current Assets | ||
Accounts receivable — trade | 171 | 153 |
Affiliated Entity | ||
Current Assets | ||
Note receivable — affiliate | 174 | 0 |
Current Liabilities | ||
Accounts payable — affiliates | $ 31 | $ 22 |
CONSOLIDATED BALANCE SHEETS (Pa
CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares | Dec. 31, 2023 | Dec. 31, 2022 |
Par value - preferred stock (in usd per share) | $ 0.01 | $ 0.01 |
Preferred stock, authorized (in shares) | 10,000,000 | 10,000,000 |
Preferred stock, issued (in shares) | 0 | 0 |
Common stock, shares authorized (in shares) | 3,000,000,000 | 3,000,000,000 |
Common stock, shares issued (in shares) | 202,080,794 | 201,972,813 |
Common stock, shares outstanding (in shares) | 202,080,794 | 201,972,813 |
Common Class A | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 500,000,000 | 500,000,000 |
Common stock, shares issued (in shares) | 34,613,853 | 34,613,853 |
Common stock, shares outstanding (in shares) | 34,613,853 | 34,613,853 |
Common Class B | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 500,000,000 | 500,000,000 |
Common stock, shares issued (in shares) | 42,738,750 | 42,738,750 |
Common stock, shares outstanding (in shares) | 42,738,750 | 42,738,750 |
Common Class C | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 1,000,000,000 | 1,000,000,000 |
Common stock, shares issued (in shares) | 82,391,441 | 82,283,460 |
Common stock, shares outstanding (in shares) | 82,391,441 | 82,283,460 |
Common Class D | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 1,000,000,000 | 1,000,000,000 |
Common stock, shares issued (in shares) | 42,336,750 | 42,336,750 |
Common stock, shares outstanding (in shares) | 42,336,750 | 42,336,750 |
CONSOLIDATED STATEMENTS OF CASH
CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Cash Flows from Operating Activities | |||
Net income (loss) | $ (14) | $ 1,060 | $ (75) |
Adjustments to reconcile net (loss) income to net cash provided by operating activities: | |||
Equity in earnings of unconsolidated affiliates | (12) | (29) | (32) |
Distributions from unconsolidated affiliates | 30 | 37 | 38 |
Depreciation, amortization and accretion | 526 | 512 | 509 |
Amortization of financing costs and debt discounts | 13 | 14 | 14 |
Amortization of intangibles | 185 | 172 | 146 |
Loss on debt extinguishment | 6 | 2 | 53 |
Reduction in carrying amount of right-of-use assets | 15 | 14 | 11 |
Gain on sale of business | 0 | (1,292) | 0 |
Impairment losses | 12 | 16 | 6 |
Change in deferred income taxes | 13 | 194 | 12 |
Changes in derivative instruments and amortization of accumulated OCI/OCL | (2) | 69 | 28 |
Cash (used in) provided by changes in other working capital | |||
Changes in prepaid and accrued liabilities for tolling agreements | (32) | 10 | 5 |
Changes in other working capital | (38) | 8 | (14) |
Net Cash Used in Operating Activities | 702 | 787 | 701 |
Cash Flows from Investing Activities | |||
Acquisitions, net of cash acquired | 0 | 0 | (533) |
Acquisition of Drop Down Assets, net of cash acquired | (45) | (71) | (229) |
Acquisition of Capistrano Wind Portfolio, net of cash acquired | 0 | (223) | 0 |
Capital expenditures | (212) | (112) | (151) |
Payment for equipment deposit | (27) | 0 | 0 |
Payment for equipment deposit and asset purchase from affiliate | (55) | 0 | (21) |
Return of investments from unconsolidated affiliates | 14 | 13 | 47 |
Increase in note receivable — affiliate | (174) | 0 | 0 |
Investments in unconsolidated affiliates | (28) | 0 | 0 |
Proceeds from sale of business | 0 | 1,457 | 0 |
Other | 4 | 1 | 22 |
Net Cash Provided by (Used in) Investing Activities | (523) | 1,065 | (865) |
Cash Flows from Financing Activities | |||
Contributions from noncontrolling interests, net of distributions | 1,028 | 60 | 967 |
Payments of dividends and distributions | (311) | (289) | (268) |
Distributions to CEG of escrowed amounts | 0 | (64) | 0 |
Tax-related distributions | (21) | (8) | 0 |
Buyout of noncontrolling interest and redeemable noncontrolling interest | (13) | 0 | 0 |
Proceeds from the revolving credit facility | 0 | 80 | 622 |
Payments for the revolving credit facility | 0 | (325) | (377) |
Proceeds from issuance of long-term debt | 563 | 244 | 1,728 |
Payments of debt issuance costs | (18) | (4) | (20) |
Payments for long-term debt | (1,349) | (1,198) | (2,292) |
Other | (3) | (6) | 7 |
Net Cash Provided by Financing Activities | (124) | (1,510) | 367 |
Reclassification of Cash to Assets Held-for-Sale | 0 | 0 | (14) |
Net Increase in Cash, Cash Equivalents and Restricted Cash | 55 | 342 | 189 |
Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 996 | 654 | 465 |
Cash, Cash Equivalents and Restricted Cash at End of Period | 1,051 | 996 | 654 |
Supplemental Disclosures: | |||
Interest paid, net of amount capitalized | (304) | (317) | (337) |
Income taxes paid | (31) | (9) | 0 |
Non-cash investing and financing activities: | |||
Non-cash adjustment for change in tax basis | 4 | (1) | (7) |
Non-cash (distributions to), contributions from noncontrolling interests | $ (7) | $ (4) | $ 31 |
CONSOLIDATED STATEMENTS OF STOC
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY - USD ($) $ in Millions | Total | Agua Caliente Acquisition | Capistrano Wind Portfolio Drop Down | Kawailoa Solar Partnership LLC | CEG | Tax Equity Investors | Preferred Stock | Common Stock | Additional Paid-In Capital | Additional Paid-In Capital CEG | (Accumulated Deficit) Retained Earnings | (Accumulated Deficit) Retained Earnings CEG | Accumulated Other Comprehensive (Loss) Income | Accumulated Other Comprehensive (Loss) Income Capistrano Wind Portfolio Drop Down | Non-controlling Interest | Non-controlling Interest Agua Caliente Acquisition | Non-controlling Interest Capistrano Wind Portfolio Drop Down | Non-controlling Interest Kawailoa Solar Partnership LLC | Non-controlling Interest CEG | Non-controlling Interest Tax Equity Investors |
Beginning balance at Dec. 31, 2020 | $ 2,715 | $ 0 | $ 1 | $ 1,922 | $ (84) | $ (14) | $ 890 | |||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||||
Net income (loss) | (79) | 51 | (130) | |||||||||||||||||
Unrealized gain on derivatives and changes in accumulated OCL, net of tax | 19 | 8 | 11 | |||||||||||||||||
Contributions from CEG, net of distributions, non-cash | $ 31 | $ 31 | ||||||||||||||||||
Contributions from noncontrolling interests, net of distributions, cash | (296) | $ (676) | (296) | $ (676) | ||||||||||||||||
Lighthouse Partnership Yield Protection Agreement Amendment | 15 | 15 | ||||||||||||||||||
Agua Caliente Acquisition | $ 273 | $ 273 | ||||||||||||||||||
Transfer of assets under common control | (374) | 94 | (468) | |||||||||||||||||
Stock-based compensation | 3 | 3 | ||||||||||||||||||
Non-cash adjustment for change in tax basis | (7) | (7) | ||||||||||||||||||
Common stock dividends and distributions to CEG | (268) | $ (155) | (113) | |||||||||||||||||
Ending balance at Dec. 31, 2021 | 3,300 | 0 | 1 | 1,872 | (33) | (6) | 1,466 | |||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||||
Net income (loss) | 1,049 | 582 | 467 | |||||||||||||||||
Unrealized gain on derivatives and changes in accumulated OCL, net of tax | 28 | 11 | 17 | |||||||||||||||||
Distributions to CEG, net of contributions, non-cash | (4) | (4) | ||||||||||||||||||
Contributions from noncontrolling interests, net of distributions, cash | (16) | (51) | (16) | (51) | ||||||||||||||||
Drop Downs | $ 11 | $ (69) | $ 4 | $ 7 | $ (69) | |||||||||||||||
Tax-related distributions | (8) | (8) | ||||||||||||||||||
Transfer of assets under common control | (58) | (29) | (29) | |||||||||||||||||
Stock-based compensation | 0 | 1 | (1) | |||||||||||||||||
Non-cash adjustment for change in tax basis | (1) | (1) | ||||||||||||||||||
Common stock dividends and distributions to CEG | (289) | $ (82) | $ (85) | (122) | ||||||||||||||||
Ending balance at Dec. 31, 2022 | 4,026 | 0 | 1 | 1,761 | 463 | 9 | 1,792 | |||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||||
Net income (loss) | (31) | 79 | (110) | |||||||||||||||||
Unrealized gain on derivatives and changes in accumulated OCL, net of tax | (6) | (2) | (4) | |||||||||||||||||
Distributions to CEG, net of contributions, non-cash | (7) | (7) | ||||||||||||||||||
Contributions from noncontrolling interests, net of distributions, cash | (78) | $ (1,123) | (78) | $ (1,123) | ||||||||||||||||
Drop Downs | (10) | 16 | (26) | |||||||||||||||||
Tax-related distributions | (21) | (21) | ||||||||||||||||||
Transfer of assets under common control | 286 | (62) | 348 | |||||||||||||||||
Stock-based compensation | 2 | 3 | ||||||||||||||||||
Non-cash adjustment for change in tax basis | 4 | 4 | ||||||||||||||||||
Common stock dividends and distributions to CEG | $ (311) | $ (180) | $ (131) | |||||||||||||||||
Ending balance at Dec. 31, 2023 | 4,994 | $ 0 | $ 1 | 1,732 | $ 361 | $ 7 | 2,893 | |||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||||||||||
Noncontrolling Interest, Decrease from Redemptions or Purchase of Reedeemable Noncontrolling Interests | $ 17 | $ 10 | $ 7 |
Nature of Business
Nature of Business | 12 Months Ended |
Dec. 31, 2023 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Nature of Business | Nature of Business Clearway Energy, Inc., together with its consolidated subsidiaries, or the Company, is a publicly-traded 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 GIP and TotalEnergies through the portfolio company, Clearway Energy Group LLC, or CEG, which is equally owned by GIP and TotalEnergies. GIP is an independent infrastructure fund manager that makes equity and debt investments in infrastructure assets and businesses. TotalEnergies is a global multi-energy company. CEG is a leading developer of renewable energy infrastructure in the U.S. The Company is one of the largest renewable energy owners in the U.S. with approximately 6,000 net MW of installed wind, solar and energy storage projects. The Company’s approximately 8,500 net MW of assets also includes approximately 2,500 net MW of environmentally-sound, highly efficient natural gas-fired generation facilities. Through this environmentally-sound, diversified and primarily contracted portfolio, the Company endeavors to provide its investors with stable and growing dividend income. The majority of the Company’s revenues are derived from long-term contractual arrangements for the output or capacity from these assets. The Company consolidates the results of Clearway Energy LLC through its controlling interest, with CEG’s interest shown as noncontrolling interest in the consolidated financial statements. The holders of the Company’s outstanding shares of Class A and Class C common stock are entitled to dividends as declared. CEG receives its distributions from Clearway Energy LLC through its ownership of Clearway Energy LLC Class B and Class D units. From time to time, CEG may also hold shares of the Company’s Class A and/or Class C common stock. As of December 31, 2023, the Company owned 57.90% of the economic interests of Clearway Energy LLC, with CEG owning 42.10% of the economic interests of Clearway Energy LLC. For further discussion, see Note 12, Stockholders’ Equity. The diagram below represents a summarized structure of the Company as of December 31, 2023: |
Summary of Significant Accounti
Summary of Significant Accounting Policies | 12 Months Ended |
Dec. 31, 2023 | |
Accounting Policies [Abstract] | |
Summary of Significant Accounting Policies | 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 project subsidiaries was $125 million and $121 million as of December 31, 2023 and 2022, respectively. 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, 2023 2022 (In millions) Cash and cash equivalents $ 535 $ 657 Restricted cash 516 339 Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 1,051 $ 996 Restricted cash consists primarily of funds held to satisfy the requirements of certain debt agreements and funds held within the Company’s projects that are restricted in their use. As of December 31, 2023, these restricted funds were comprised of $176 million designated to fund operating expenses, $178 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 $77 million is held in distributions 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, 2023 2022 2021 (In millions) Cash paid to acquire Drop Down Assets $ (173) $ (71) $ (230) Cash acquired from the acquisition of Drop Down Assets 128 — 1 Acquisition of Drop Down Assets, net of cash acquired $ (45) $ (71) $ (229) 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, 2023 and 2022. 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 income. 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, 2023, 2022 and 2021 was $36 million, $2 million and $3 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 income. 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 power purchase agreements, 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 . 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. Conventional Generation Revenues The majority of the conventional energy plants commenced merchant operations during 2023 following the expiration of the PPAs. These facilities generate revenues from selling electricity and/or RA to the California Independent System Operator and to public utility and load serving entities, as the power is delivered at the interconnection point. Thermal Revenues On May 1, 2022, the Company completed the sale of 100% of its interests in the Thermal Business to KKR. For further details of the Thermal Disposition refer to Note 3, Acquisitions and Dispositions. Prior to the Thermal Disposition, steam and chilled water revenue was recognized as the Company transferred the product to the customer, based on customer usage as determined by meter readings taken at month-end. Some locations read customer meters throughout the month and recognized estimated revenue for the period between meter read date and month-end. For thermal contracts, the Company’s performance obligation to deliver steam and chilled water was satisfied over time and revenue was recognized based on the invoiced amount. The Thermal Business subsidiaries collected and remitted state and local taxes associated with sales to their customers, as required by governmental authorities. These taxes were presented on a net basis in the consolidated statements of income. 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 conventional energy plants is 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 conventional energy plants 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, 2023, 2022 and 2021 was $780 million, $850 million and $741 million, respectively. See Note 17, 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 often 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, 2023 (In millions) Conventional Generation Renewables Total Energy revenue (a) $ 81 $ 942 $ 1,023 Capacity revenue (a) 336 23 359 Other revenue (a) 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 17, Leases, for the amounts of energy, capacity and other revenue that relate to leases and are accounted for under ASC 842. Year ended December 31, 2022 (In millions) Conventional Generation Renewables Thermal Total Energy revenue (a) $ 6 $ 956 $ 48 $ 1,010 Capacity revenue (a) 435 2 18 455 Other revenue — 71 11 82 Contract amortization (24) (151) — (175) Mark-to-market for economic hedges — (182) — (182) Total operating revenues 417 696 77 1,190 Less: Contract amortization 24 151 — 175 Less: Mark-to-market for economic hedges — 182 — 182 Less: Lease revenue (441) (809) (1) (1,251) Total revenue from contracts with customers $ — $ 220 $ 76 $ 296 (a) See Note 17, Leases , for the amounts of energy and capacity revenue that relate to leases and are accounted for under ASC 842. Year ended December 31, 2021 (In millions) Conventional Generation Renewables Thermal Total Energy revenue (a) $ 9 $ 784 $ 122 $ 915 Capacity revenue (a) 455 2 53 510 Other revenue — 60 32 92 Contract amortization (23) (118) (3) (144) Mark-to-market for economic hedges — (87) — (87) Total operating revenues 441 641 204 1,286 Less: Contract amortization 23 118 3 144 Less: Mark-to-market for economic hedges — 87 — 87 Less: Lease revenue (464) (716) (2) (1,182) Total revenue from contracts with customers $ — $ 130 $ 205 $ 335 (a) See Note 17, Leases , for the amounts of energy and capacity revenue 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 and liabilities included on the Company’s consolidated balance sheets: (In millions) December 31, 2023 December 31, 2022 Accounts receivable, net - Contracts with customers $ 66 $ 37 Accounts receivable, net - Leases 105 116 Total accounts receivable, net $ 171 $ 153 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 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 for conventional facilities. 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 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 would be immediately reclassified into earnings. If the derivative financial instrument is terminated, the effective portion of this derivative deferred in accumulated OCI 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 projects have only one customer. See Item 1A, Risk Factors, Risks Related to the Company’s Business, for a discussion on the Company’s dependence on major customers . See Note 6, Fair Value of Financial Instruments, for a further discussion of derivative concentrations and Note 13, Segment Reporting , for concentration of counterparties. Fair Value of Financial Instruments The carrying amount of cash and cash equivalents, restricted cash, accounts receivable — trade, note receivable — affiliate, accounts payable — trade, account 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 ARO obligations, along with the related activity: (In millions) Balance as of December 31, 2022 $ 157 Revisions in estimated cash flows 3 Liabilities incurred 67 Accretion expense 12 Balance as of December 31, 2023 $ 239 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 projects 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 projects. 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 840-40, 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. Income Taxes The Company accounts for income taxes using the liability method in accordance with ASC 740, Income Taxes , or ASC 740, which requires that the Company use the asset and liability method of accounting for deferred income taxes and provide deferred income taxes for all significant temporary differences. The Company has two categories of income tax expense or benefit — current and deferred, as follows: • Current income tax expense or benefit consists solely of current taxes payable less applicable tax credits, and • Deferred income tax expense or benefit is the change in the net deferred income tax asset or liability, excluding amounts charged or credited to accumulated other comprehensive income (loss). The Company reports some of its revenues and expenses differently for financial statement purposes than for income tax return purposes, resulting in temporary and permanent differences between the Company’s financial statements and income tax returns. The tax effects of such temporary differences are recorded as either deferred income tax assets or deferred income tax liabilities in the Company’s consolidated balance sheets. The Company measures its deferred income tax assets and deferred income tax liabilities using income tax rates that are currently in effect. The Company believes it is more likely than not that the results of future operations will generate sufficient taxable income which includes the future reversal of existing taxable temporary differences to realize deferred tax assets, net of valuation allowances. In arriving at this conclusion to utilize projections of future profit before tax in its estimate of future taxable income, the Company considered the profit before tax generated in recent years. A valuation allowance is recorded to reduce the net deferred tax assets to an amount that is more-likely-than-not to be realized. The Company accounts for uncertain tax positions in accordance with ASC 740, which applies to all tax positions related to income taxes. Under ASC 740, tax benefits are recognized when it is more-likely-than-not that a tax position will be sustained upon examination by the authorities. The benefit recognized from a position that has surpassed the more-likely-than-not threshold is the largest amount of benefit that is more than 50% likely to be realized upon settlement. In accordance with ASC 740 and as discussed further in Note 14, Income Taxes , changes to existing net deferred tax assets, valuation allowances, or changes to uncertain tax benefits, are recorded to income tax expense. 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 noncontrolling interest. 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 certain tax equity arrangements, which are consolidated by the Company, that have been entered into to finance the cost of solar and wind facilities eligible for certain tax credits. The Company has determined that the provisions in the contractual agreements of these structures 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 income 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. During the fourth quarter of 2023, the Company repurchased a partner’s equity interest, 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, 2021 $ — Cash distributions to redeemable noncontrolling interests (4) Comprehensive income attributable to redeemable noncontrolling interests 11 Balance at December 31, 2022 7 Cash distributions to redeemable noncontrolling interests (3) Comprehensive income attributable to redeemable noncontrolling interests 17 Repurchase of redeemable noncontrolling interest (20) Balance at December 31, 2023 $ 1 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, tax provisions, 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. Reclassification Certain prior year am |
Acquisitions and Dispositions
Acquisitions and Dispositions | 12 Months Ended |
Dec. 31, 2023 | |
Business Combination and Asset Acquisition [Abstract] | |
Acquisitions and Dispositions | 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. Texas Solar Nova 1 Drop Down — On December 28, 2023, the Company, through its indirect subsidiary, Lighthouse Renewable Holdco 2 LLC, acquired TSN1 BL Borrower Holdco LLC, the indirect owner of Texas Solar Nova 1, a 252 MW solar project that is located in Kent County, Texas, from Clearway Renew for cash consideration of $23 million. Lighthouse Renewable Holdco 2 LLC is a partnership between the Company and a cash equity investor. The cash equity investor also contributed cash consideration of $109 million to acquire their portion of the acquired entity. TSN1 BL Borrower Holdco LLC consolidates as primary beneficiary, TSN1 TE Holdco LLC, a tax equity fund that owns the Texas Solar Nova 1 solar project, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities . Texas Solar Nova 1 has an 18-year PPA with an investment-grade counterparty that commenced in January 2024. The Texas Solar Nova 1 operations are reflected in the Company’s Renewables segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Texas Solar Nova 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 sum of the cash paid of $23 million and the historical cost of the Company’s net liabilities assumed of $6 million was recorded as an adjustment to CEG’s noncontrolling interest balance. In addition, the Company reflected the entire $23 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 distributions to CEG, net of contributions in the consolidated statements of stockholders’ equity. The following is a summary of assets and liabilities transferred in connection with the acquisition as of December 28, 2023: (In millions) Texas Solar Nova 1 Cash $ 3 Property, plant and equipment 362 Right-of-use assets, net 21 Derivative assets 4 Other non-current assets 6 Total assets acquired 396 Long-term debt (a) 349 Long-term lease liabilities 19 Other current and non-current liabilities 34 Total liabilities assumed 402 Net liabilities assumed $ (6) (a) Includes a $90 million construction loan, $109 million sponsor equity bridge loan and $151 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. Rosamond Central BESS Drop Down — On December 1, 2023, the Rosamond Central solar project acquired a 147 MW BESS project that is co-located at the Rosamond Central solar 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 cash equity investor in Rosie TargetCo LLC and the tax equity investor in Rosie TE HoldCo LLC. At substantial completion, which is expected to occur in the first half of 2024, the Company estimates it will pay an additional $279 million to Clearway Renew, $61 million of which will be funded by the Company with the remaining $218 million to be funded through contributions from the cash equity and tax equity investors. In order to facilitate and fund the construction of the BESS project, Rosie Class B LLC, the indirect owner of the Rosamond Central solar project, utilizing the proceeds from borrowings received under the refinanced debt facility, issued a loan to Clearway Renew that is included in note receivable — affiliate on the Company’s consolidated balance sheet, as further discussed in Note 10, Long-term Debt , and also made equity contributions to Rosie BESS Devco LLC, or Rosie Central BESS, which is an investment accounted for under the equity method of accounting, as further discussed in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities . The BESS project has a PPA for capacity with an investment-grade utility that has a 15-year contract duration that commences when the project reaches commercial operations, which is expected to occur in the first half of 2024. The Rosamond Central BESS operations are reflected in the Company’s Renewables segment and the Company’s portion of the initial consideration was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates the Rosamond Central BESS project 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 cash paid of $70 million was recorded as an adjustment to CEG’s noncontrolling interest balance. 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 project that is paired with 50 MW of energy storage, and Arica, a 263 MW solar project that is paired with 136 MW of energy storage, which are both currently under construction in Riverside, California, from Clearway Renew for initial cash consideration of $46 million. Simultaneously, a cash equity investor acquired the Class B membership interests in VP-Arica TargetCo LLC from Clearway Renew for initial cash consideration of $87 million. At substantial completion, which is expected to occur in the first half of 2024, the Company estimates it will pay an additional $182 million to Clearway Renew and the cash equity investor will contribute 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 projects, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities . 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 commence when the underlying operating assets reach commercial operations, which is expected to occur in the first half of 2024. The Victory Pass and Arica operations are reflected in the Company’s Renewables 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 cash paid of $46 million and the historical cost of the Company’s net liabilities assumed of $1 million was recorded as an adjustment to CEG’s noncontrolling interest balance. In addition, the Company reflected the entire $46 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 distributions to CEG, net of contributions in the consolidated statements of stockholders’ 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. (b) Includes a $483 million sponsor 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. Daggett 2 Drop Down — On August 30, 2023, the Company, through its indirect subsidiary, Daggett Solar Investment LLC, acquired the Class A membership interests in Daggett 2 TargetCo LLC, a partnership and the indirect owner of Daggett 2, a 182 MW solar project that is paired with 131 MW of energy storage and is located in San Bernardino, California, from CEG for cash consideration of $13 million. Daggett 2 TargetCo LLC consolidates as primary beneficiary, Daggett 2 TE Holdco LLC, a tax equity fund that owns the Daggett 2 solar project, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. Daggett 2 has PPAs with investment-grade counterparties that have a 15-year weighted average contract duration that commenced in December 2023. The Daggett 2 operations are reflected in the Company’s Renewables 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 2 on a prospective basis in its financial statements. The assets, liabilities and noncontrolling interests 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 historical cost of the Company’s acquired interests of $29 million and the cash paid of $13 million was recorded as an adjustment to CEG’s noncontrolling interest balance. The following is a summary of assets and liabilities transferred in connection with the acquisition as of August 30, 2023: (In millions) Daggett 2 Cash $ 1 Restricted cash (a) 119 Property, plant and equipment 379 Right-of-use assets, net 22 Derivative assets 22 Total assets acquired 543 Long-term debt (b) 308 Long-term lease liabilities 23 Other current and non-current liabilities 28 Total liabilities assumed 359 Noncontrolling interests 213 Net assets acquired less noncontrolling interests $ (29) (a) Includes funds that were contributed by the cash equity investor and tax equity investor, which were primarily used to pay off the tax equity bridge loan when the project reached substantial completion on December 22, 2023, as further discussed in Note 10, Long-term Debt . (b) Includes a $107 million construction loan and $204 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. Daggett 3 Drop Down — On February 17, 2023, the Company, through its indirect subsidiary, Daggett Solar Investment LLC, acquired the Class A membership interests in Daggett TargetCo LLC, the indirect owner of Daggett 3, a 300 MW solar project that is paired with 149 MW of energy storage and located in San Bernardino, California, from Clearway Renew for cash consideration of $21 million. Simultaneously, a cash equity investor acquired the Class B membership interests in Daggett TargetCo LLC from Clearway Renew for cash consideration of $129 million. The Company and the cash equity investor then contributed their Class A and B membership interests, respectively, into Daggett Renewable Holdco LLC, a partnership that consolidates Daggett TargetCo LLC. Daggett TargetCo LLC consolidates as primary beneficiary, Daggett TE Holdco LLC, a tax equity fund that owns the Daggett 3 solar project, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. Daggett 3 has PPAs with investment-grade counterparties that have a 15-year weighted average contract duration that commenced between July 2023 and November 2023. The Daggett 3 operations are reflected in the Company’s Renewables 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 3 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 cash paid of $21 million and the historical cost of the Company’s net assets acquired of $15 million was recorded as an adjustment to CEG’s noncontrolling interest balance. In addition, the Company reflected the entire $21 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 distributions to CEG, net of contributions in the consolidated statements of stockholders’ equity. The following is a summary of assets and liabilities transferred in connection with the acquisition as of February 17, 2023: (In millions) Daggett 3 Restricted cash $ 4 Property, plant and equipment 534 Right-of-use assets, net 31 Derivative assets 27 Total assets acquired 596 Long-term debt (a) 480 Long-term lease liabilities 33 Other current and non-current liabilities (b) 68 Total liabilities assumed 581 Net assets acquired $ 15 (a) Includes a $181 million construction loan, $75 million sponsor equity bridge loan and $229 million tax equity bridge loan, offset by $5 million in unamortized debt issuance costs. See Note 10, Long-term Debt , for further discussion of the long-term debt assumed in the acquisition. (b) Includes $32 million of project costs that were subsequently funded by CEG. Subsequent to the acquisition date, CEG funded an additional $22 million in project costs. The combined $54 million funded by CEG was repaid to CEG in October 2023. Waiawa Drop Down — On October 3, 2022, the Company, through its indirect subsidiary, Lighthouse Renewable Holdco LLC, acquired Waiawa BL Borrower Holdco LLC, the indirect owner of the Waiawa solar project, a 36 MW solar project that is paired with 36 MW of energy storage and located in Honolulu, Hawaii, from Clearway Renew for cash consideration of $20 million. Lighthouse Renewable Holdco LLC is a partnership between the Company and a cash equity investor. The cash equity investor also contributed cash consideration of $12 million, which was utilized to acquire their portion of the acquired entity. At the time of the acquisition, Waiawa BL Borrower Holdco LLC consolidated as primary beneficiary, Waiawa TE Holdco LLC, a tax equity fund that held the Waiawa solar project. Waiawa has a 20-year PPA with an investment-grade utility that commenced in January 2023. The Waiawa solar project is reflected in the Company’s Renewables segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Waiawa 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 cash paid of $20 million and the historical cost of the Company’s net liabilities assumed of $1 million was recorded as an adjustment to CEG’s noncontrolling interest balance. In addition, the Company reflected $16 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 distributions to CEG, net of contributions, in the consolidated statement of stockholders’ equity. The following is a summary of assets and liabilities transferred in connection with the acquisition as of October 3, 2022: (In millions) Waiawa Other current and non-current assets $ 7 Property, plant and equipment 118 Total assets acquired 125 Long-term debt (a) 102 Other current and non-current liabilities 24 Total liabilities assumed 126 Net liabilities assumed $ (1) (a) Includes a $22 million construction loan, $26 million sponsor equity bridge loan and $55 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. Capistrano Wind Portfolio Acquisition — On August 22, 2022, the Company, through its wholly-owned indirect subsidiary, Capistrano Portfolio Holdco LLC, acquired the Capistrano Wind Portfolio from Capistrano Wind Partners LLC, an indirect subsidiary of CEG, for a base purchase price of approximately $255 million, less working capital adjustments in the net amount of approximately $16 million, representing total net consideration of approximately $239 million. Concurrent with the acquisition, the Company also entered into a development agreement with Clearway Renew, whereby Clearway Renew paid $10 million to the Company at acquisition date for an exclusive right to develop, construct and repower the projects in the Capistrano Wind Portfolio, which was utilized to partially fund the acquisition of the Capistrano Wind Portfolio. The Capistrano Wind Portfolio consists of five wind projects located in Texas, Nebraska and Wyoming with a combined capacity of 413 MW that reached commercial operations between 2008 and 2012. The assets within the portfolio sell power under PPAs with investment-grade counterparties that have a weighted average remaining contract duration of approximately 8 years. The Capistrano Wind Portfolio operations are reflected in the Company’s Renewables 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 Capistrano Wind 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 transferred at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues , which reflects GIP’s basis. The difference between the historical cost of the Company’s net assets acquired of $250 million, less the sum of the cash paid of $239 million and the $4 million in accumulated other comprehensive income transferred to the Company, was recorded as an adjustment to CEG’s noncontrolling interest balance. The following is a summary of assets and liabilities transferred in connection with the acquisition as of August 22, 2022: (In millions) Capistrano Wind Portfolio Other current and non-current assets (a) $ 39 Property, plant and equipment, net 147 Intangible assets for power purchase agreements 237 Right-of-use assets, net 27 Total assets acquired 450 Long-term debt 162 Long-term lease liabilities 28 Other current and non-current liabilities 10 Total liabilities assumed 200 Net assets acquired $ 250 (a) Includes cash of $12 million and restricted cash of $4 million. Mililani I Drop Down — On March 25, 2022, the Company, through its indirect subsidiary, Lighthouse Renewable Holdco LLC, acquired Mililani BL Borrower Holdco LLC, the indirect owner of the Mililani I solar project, a 39 MW solar project that is paired with 39 MW of energy storage and located in Honolulu, Hawaii, from Clearway Renew for cash consideration of $22 million. The cash equity investor in Lighthouse Renewable Holdco LLC also contributed cash consideration of $14 million utilized to acquire their portion of the acquired entity. Mililani BL Borrower Holdco LLC consolidates as primary beneficiary, Mililani TE Holdco LLC, a tax equity fund that owns the Mililani I solar project. Mililani I has a 20-year PPA with an investment-grade utility that commenced in July 2022. The Mililani I operations are reflected in the Company’s Renewables segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and the Company consolidates Mililani 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 cash paid of $22 million and the historical cost of the Company’s net liabilities assumed of $8 million was recorded as an adjustment to CEG’s noncontrolling interest balance. In addition, the Company reflected $15 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 distributions to CEG, net of contributions, in the consolidated statement of stockholders’ equity. The following is a summary of assets and liabilities transferred in connection with the acquisition as of March 25, 2022: (In millions) Mililani I Other current and non-current assets $ 2 Property, plant and equipment 118 Right-of-use assets 19 Total assets acquired 139 Long-term debt (a) 100 Long-term lease liabilities 20 Other current and non-current liabilities 27 Total liabilities assumed 147 Net liabilities assumed $ (8) (a) Includes a $16 million construction loan, $27 million sponsor equity bridge loan and $60 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. Dispositions Kawailoa Sale — On August 1, 2022, the Company sold 100% of its Class A membership interests in the Kawailoa Partnership to Clearway Renew for cash proceeds of $9 million, which equals the Company’s initial investment. The Kawailoa Partnership is a partnership that consolidates, through its 51% controlling majority interest, a lower-level partnership that is 49% owned by a cash equity investor, and which consolidates the Kawailoa solar project through its ownership of a controlling interest in the tax equity fund that holds the project. The assets and liabilities transferred to Clearway Renew relate to interests under common control and were transferred at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues . This resulted in the Company removing $69 million from noncontrolling interest related to the Kawailoa Partnership at the time of sale. Noncontrolling interests prior to the sale include the interests of the cash equity investor, tax equity investor and Clearway Renew. Thermal Disposition — On May 1, 2022, the Company completed the sale of 100% of its interests in the Thermal Business to KKR for net proceeds of approximately $1.46 billion, inclusive of working capital adjustments, which excludes approximately $18 million in transaction expenses that were incurred in connection with the disposition. The Thermal Disposition resulted in a gain on sale of business of approximately $1.29 billion, which is net of the $18 million in transaction expenses referenced above. The proceeds from the sale were utilized to repay certain borrowings outstanding as further described in Note 10, Long-term Debt , with the remaining proceeds invested in short-term investments classified as cash and cash equivalents on the Company’s consolidated balance sheet. The Company’s Thermal segment was comprised solely of the Thermal Business’s results of operations. |
Property, Plant and Equipment
Property, Plant and Equipment | 12 Months Ended |
Dec. 31, 2023 | |
Property, Plant and Equipment [Abstract] | |
Property, Plant and Equipment | Property, Plant and Equipment The Company’s major classes of property, plant, and equipment were as follows: December 31, 2023 December 31, 2022 Depreciable Lives (In millions) Facilities and equipment $ 11,426 $ 9,992 3 - 41 Years Land and improvements 365 293 Construction in progress (a) (b) 1,220 160 Total property, plant and equipment 13,011 10,445 Accumulated depreciation (3,485) (3,024) Net property, plant and equipment $ 9,526 $ 7,421 (a) As of December 31, 2023 and 2022, construction in progress includes $21 million and $17 million, respectively, of capital expenditures that relate to prepaid long-term service agreements in the Conventional segment. (b) As of December 31, 2023 and 2022, construction in progress includes $72 million and $9 million, respectively, of accrued capital expenditures. Depreciation expense related to property, plant and equipment during the years ended December 31, 2023, 2022 and 2021 was $514 million, $502 million and $499 million, respectively. The Company recorded long-lived asset impairments during each of the years ended December 31, 2023, 2022 and 2021, as further described in Note 9, Asset Impairments. |
Investments Accounted for by th
Investments Accounted for by the Equity Method and Variable Interest Entities | 12 Months Ended |
Dec. 31, 2023 | |
Equity Method Investments and Joint Ventures [Abstract] | |
Investments Accounted for by the Equity Method and Variable Interest Entities | Investments Accounted for by the Equity Method and Variable Interest Entities Equity Method Investments The Company’s maximum exposure to loss as of December 31, 2023 is limited to its equity investment in the unconsolidated entities, as further summarized in the table below: Name Economic Interest Investment Balance (In millions) Avenal 50% $ 7 Desert Sunlight 25% 224 Elkhorn Ridge 66.7% 15 GenConn (a) 50% 79 Rosie Central BESS (a) 50% 28 San Juan Mesa 75% 7 $ 360 (a) GenConn and Rosie Central BESS are variable interest entities. As of December 31, 2023 and 2022, the Company had $17 million and $19 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 difference between the purchase price and the basis of the acquired assets and liabilities of $181 million. The difference is attributable to the fair value of the property, plant and equipment and power purchase agreements. 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, 2023, the carrying value of the basis difference is $122 million. The Company’s pro-rata share of non-recourse debt held by unconsolidated affiliates was $303 million as of December 31, 2023. Rosie Central BESS — On June 30, 2023, the Company, through its indirect subsidiary, Rosie Class B LLC, the indirect owner of the Rosamond Central solar project, became the owner of the Class B membership interests of Rosie Central BESS in order to facilitate and fund the construction of a BESS project that is co-located at the Rosamond Central solar facility. Clearway Renew indirectly owns the Class A membership interests and controls Rosie Central BESS. The Company accounts for its investment in Rosie Central BESS as an equity method investment. As of December 31, 2023, the Company’s investment consisted of $28 million contributed into Rosie Central BESS, funded through contributions from the Company and its cash equity investor in Rosie TargetCo LLC, which consolidates Rosie Class B LLC. On December 1, 2023, the Rosamond Central solar project acquired the BESS project from Clearway Renew, as further discussed in Note 3, Acquisitions and Dispositions . When the BESS project reaches substantial completion, which is expected to occur in the first half of 2024, Clearway Renew will return Rosie Class B LLC’s equity investment. The following tables present summarized financial information for the Company’s equity method investments: Year Ended December 31, 2023 2022 2021 Income Statement Data: (In millions) GenConn Operating revenues $ 51 $ 50 $ 55 Operating income 14 16 22 Net income 6 7 13 Desert Sunlight Operating revenues 202 203 205 Operating income 144 137 146 Net income 108 114 112 Other (a) Operating revenues 43 52 49 Operating income 9 18 16 Net income 7 15 13 As of December 31, 2023 2022 Balance Sheet Data: (In millions) GenConn Current assets $ 39 $ 39 Non-current assets 294 312 Current liabilities 15 16 Non-current liabilities 162 170 Desert Sunlight Current assets 80 79 Non-current assets 1,131 1,175 Current liabilities 61 61 Non-current liabilities 776 824 Other (a) Current assets 19 22 Non-current assets 135 157 Current liabilities 13 12 Non-current liabilities 81 91 (a) Includes Avenal, Elkhorn Ridge, San Juan Mesa and Rosie Central BESS. 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 and solar 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 2023 related to the Company’s consolidated VIEs: DGPV Funds — On December 29, 2023, the Company, through its indirect subsidiary, DGPV 4 LLC, acquired 100% of the Class A membership interests in DGPV Fund 4 LLC, a tax equity fund that owns several distributed solar projects, from the tax equity investor in DGPV Fund 4 LLC for $3 million. Prior to the acquisition, the Company consolidated DGPV Fund 4 LLC through its ownership of the Class B membership interests and role as managing member and the Class A membership interests were reflected as redeemable noncontrolling interest on the Company’s consolidated balance sheet. The difference between the historical cost of the Company’s redeemable noncontrolling interest of $20 million and the cash paid of $3 million was recorded as an adjustment between additional paid-in capital and CEG’s noncontrolling interest balance. Alta TE Holdco — On December 6, 2023, the Company, through its indirect subsidiary, Clearway Energy Operating LLC, acquired 100% of the Class A membership interests in Alta X-XI TE Holdco, LLC, or Alta TE Holdco, a tax equity fund that owns the Alta X and XI wind projects, from the tax equity investor in Alta TE Holdco for $10 million. Prior to the acquisition, the Company consolidated Alta TE Holdco 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 of $37 million and the cash paid of $10 million was recorded as an adjustment between additional paid-in capital and CEG’s noncontrolling interest balance. Lighthouse Partnerships As described in Note 3, Acquisitions and Dispositions , on December 28, 2023, Lighthouse Renewable Holdco 2 LLC, an indirect subsidiary of the Company, acquired TSN1 BL Borrower Holdco LLC. The Company consolidates Lighthouse Renewable Holdco 2 LLC, a partnership between the Company and a cash equity investor, as a VIE as the Company is the primary beneficiary, through its role as managing member. The Company recorded the noncontrolling interest of the cash equity investor in TSN1 BL Borrower Holdco LLC at historical carrying amount, with the offset to additional paid-in capital. TSN1 BL Borrower Holdco LLC consolidates as primary beneficiary, TSN1 TE Holdco LLC, a tax equity fund that owns the Texas Solar Nova 1 solar project. The Class A membership interests in TSN1 TE Holdco LLC are held by a tax equity investor and are reflected as noncontrolling interest on the Company’s consolidated balance sheet. On August 30, 2023, the Company and the cash equity investor in Lighthouse Renewable Holdco LLC and Lighthouse Renewable Holdco 2 LLC agreed to transfer Mesquite Star Class B Holdco LLC, the indirect owner of the Mesquite Star wind project, from Lighthouse Renewable Holdco LLC to Lighthouse Renewable Holdco 2 LLC. As the transfer was among entities under common control, the transaction was recognized at historical cost and no gain or loss was recognized. VP-Arica TargetCo LLC — As described in Note 3, Acquisitions and Dispositions , on October 31, 2023, VP-Arica Parent Holdco LLC, an indirect subsidiary of the Company, acquired the Class A membership interests in VP-Arica TargetCo LLC, which is a partnership. The Company consolidates VP-Arica TargetCo LLC as a VIE as the Company is the primary beneficiary. Through its membership interests in VP-Arica TargetCo LLC, the Company receives 40% of distributable cash. The Company recorded the noncontrolling interest of the cash equity investor in VP-Arica TargetCo LLC at historical carrying amount, with the offset to additional paid-in capital. VP-Arica TargetCo LLC consolidates as primary beneficiary and through its ownership of the Class B membership interests, VP-Arica TE Holdco LLC, a tax equity fund that owns the Victory Pass and Arica solar projects. The Class A membership interests in VP-Arica TE Holdco LLC are held by a tax equity investor and are reflected as noncontrolling interest on the Company’s consolidated balance sheet. Daggett Partnerships As described in Note 3, Acquisitions and Dispositions , on August 30, 2023, Daggett Solar Investment LLC, an indirect subsidiary of the Company, acquired the Class A membership interests in Daggett 2 TargetCo LLC, which is a partnership. The Company consolidates Daggett 2 TargetCo LLC as a VIE as the Company is the primary beneficiary, through its role as managing member. Through its membership interests in Daggett 2 TargetCo LLC, the Company receives 25% of distributable cash. The Company recorded the acquired noncontrolling interest of the cash equity investor in Daggett 2 TargetCo LLC at historical carrying amount. Daggett 2 TargetCo LLC consolidates as primary beneficiary and through its ownership of the Class B membership interests, Daggett 2 TE Holdco LLC, a tax equity fund that owns the Daggett 2 solar project. The Class A membership interests in Daggett 2 TE Holdco LLC are held by a tax equity investor and are reflected as noncontrolling interest on the Company’s consolidated balance sheet. As described in Note 3, Acquisitions and Dispositions , on February 17, 2023, Daggett Solar Investment LLC acquired the Class A membership interests in Daggett TargetCo LLC while a cash equity investor acquired the Class B membership interests. The Company and the cash equity investor then contributed their Class A and B membership interests, respectively, into Daggett Renewable Holdco LLC, which is a partnership, and concurrently, Daggett TargetCo LLC became a wholly-owned subsidiary of Daggett Renewable Holdco LLC. Through its membership interests in Daggett Renewable Holdco LLC, the Company receives 25% of distributable cash. The Company consolidates Daggett Renewable Holdco LLC as a VIE as the Company is the primary beneficiary, through its role as managing member. The Company recorded the noncontrolling interest of the cash equity investor in Daggett Renewable Holdco LLC at historical carrying amount, with the offset to additional paid-in capital. Daggett TargetCo LLC consolidates as primary beneficiary and through its ownership of the Class B membership interests, Daggett TE Holdco LLC, a tax equity fund that owns the Daggett 3 solar project. The Class A membership interests in Daggett TE Holdco LLC are held by a tax equity investor and are reflected as noncontrolling interest on the Company’s consolidated balance sheet. Summarized financial information for the Company’s consolidated VIEs consisted of the following as of December 31, 2023: (In millions) Buckthorn Holdings, LLC DGPV Funds (a) Langford TE Partnership LLC Daggett Partnerships (b) Lighthouse Renewable Holdco LLC (c) Lighthouse Renewable Holdco 2 LLC (d) Other current and non-current assets $ 4 $ 58 $ 23 $ 167 $ 68 $ 135 Property, plant and equipment 185 381 115 988 415 1,086 Intangible assets — 1 — — — 2 Total assets 189 440 138 1,155 483 1,223 Current and non-current liabilities 12 50 63 464 139 447 Total liabilities 12 50 63 464 139 447 Noncontrolling interest 15 3 66 827 254 590 Net assets less noncontrolling interest $ 162 $ 387 $ 9 $ (136) $ 90 $ 186 (a) DGPV Funds is comprised of Clearway & EFS Distributed Solar LLC, Golden Puma Fund LLC, Renew Solar CS4 Fund LLC and Chestnut Fund LLC, which are all tax equity funds. (b) Daggett Partnerships includes Daggett 2 TargetCo LLC, which consolidates Daggett 2 TE Holdco LLC, a consolidated VIE, and Daggett Renewable Holdco LLC, which consolidates Daggett TE Holdco LLC, a consolidated VIE. (c) Lighthouse Renewable Holdco LLC consolidates Black Rock TE Holdco LLC and Mililani TE Holdco LLC, which are consolidated VIEs. (d) Lighthouse Renewable Holdco 2 LLC consolidates Mesquite Sky TE Holdco LLC, Mesquite Star Tax Equity Holdco LLC and TSN1 TE Holdco LLC, which are consolidated VIEs. (In millions) Oahu Solar LLC Rattlesnake TE Holdco LLC Rosie TargetCo LLC VP-Arica TargetCo LLC (a) Wildorado TE Holdco LLC Other (b) Other current and non-current assets $ 38 $ 13 $ 298 $ 101 $ 20 $ 24 Property, plant and equipment 157 176 507 960 194 238 Intangible assets — — — — — 16 Total assets 195 189 805 1,061 214 278 Current and non-current liabilities 22 17 376 834 18 85 Total liabilities 22 17 376 834 18 85 Noncontrolling interest 23 77 181 67 99 95 Net assets less noncontrolling interest $ 150 $ 95 $ 248 $ 160 $ 97 $ 98 (a) VP-Arica TargetCo LLC consolidates VP-Arica TE Holdco LLC, a consolidated VIE that owns the Victory Pass and Arica solar projects. (b) Other is comprised of Elbow Creek TE Holdco LLC, Pinnacle Repowering TE Holdco LLC and the Spring Canyon projects. |
Fair Value of Financial Instrum
Fair Value of Financial Instruments | 12 Months Ended |
Dec. 31, 2023 | |
Fair Value Disclosures [Abstract] | |
Fair value of Financial Instruments | 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, note receivable — affiliate, accounts payable — trade, accounts payable — affiliates and accrued expenses and other current liabilities, the carrying amounts approximates 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, 2023 As of December 31, 2022 Carrying Amount Fair Value Carrying Amount Fair Value (In millions) Liabilities: Long-term debt, including current portion (a) $ 8,102 $ 7,611 $ 6,874 $ 6,288 (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, 2023 As of December 31, 2022 Level 2 Level 3 Level 2 Level 3 (In millions) Long-term debt, including current portion $ 1,939 $ 5,672 $ 1,834 $ 4,454 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, 2023 As of December 31, 2022 Fair Value Fair Value (a) Fair Value Fair Value (a) (In millions) Level 2 (b) Level 3 Level 2 Level 3 Derivative assets Energy-related commodity contracts (c) $ 2 $ — $ — $ — Interest rate contracts 121 — 89 — Other financial instruments (d) — 13 — 17 Total assets $ 123 $ 13 $ 89 $ 17 Derivative liabilities Energy-related commodity contracts (e) $ — $ 330 $ — $ 353 Interest rate contracts 2 — — — Total liabilities $ 2 $ 330 $ — $ 353 (a) There were no derivative assets or liabilities classified as Level 1 as of December 31, 2023 and 2022. (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 long-term backbone transportation service contracts entered into by El Segundo and Walnut Creek during 2023. (d) Includes SREC contract. (e) Includes $325 million related to long-term power commodity contracts and $5 million related to short-term heat rate call option contracts entered into by El Segundo, Marsh Landing and Walnut Creek during 2023. 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, 2023 2022 (In millions) Fair Value Measurement Using Significant Unobservable Inputs (Level 3) Beginning balance $ (336) $ (154) Settlements 28 61 Additions due to loss of NPNS exception — (22) Total losses for the period included in earnings (9) (221) Ending balance $ (317) $ (336) Change in unrealized losses included in earnings for derivatives and other financial instruments held as of December 31, $ (9) $ (221) 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, 2023, contracts valued with prices provided by models and other valuation techniques make up 99% of derivative liabilities and 100% of other financial instruments. The Company’s significant positions classified as Level 3 include physical and financial energy-related commodity 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 table quantifies the significant unobservable inputs used in developing the fair value of the Company’s Level 3 positions as of December 31, 2023: December 31, 2023 Fair Value Input/Range Assets Liabilities Valuation Technique Significant Unobservable Input Low High Weighted Average (In millions) Long-term Power Commodity Contracts $ — $ 325 Discounted Cash Flow Forward Market Price (per MWh) $ 18.18 $ 81.62 $ 39.91 Heat Rate Call Option Commodity Contracts — 5 Option Model Forward Market Price (per MWh) $ (43.96) $ 343.61 $ 64.34 Option Model Forward Market Price (per MMBtu) $ 1.25 $ 13.69 $ 4.93 Other Financial Instruments 13 — Discounted Cash Flow Forecast annual generation levels of certain DG solar facilities 60,801 MWh 121,602 MWh 115,622 MWh The following table provides the impact on the fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2023: 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, 2023, the non-performance reserve was a $15 million gain recorded primarily to total operating revenues in the consolidated statements of income. 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. |
Accounting for Derivative Instr
Accounting for Derivative Instruments and Hedging Activities | 12 Months Ended |
Dec. 31, 2023 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Accounting for Derivative Instruments and Hedging Activities | 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. As of December 31, 2023, the Company had interest rate derivative instruments on non-recourse debt extending through 2040, 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, 2023, the Company had energy-related derivative instruments extending through 2033. At December 31, 2023, 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, 2023 December 31, 2022 Commodity Units (In millions) Power MWh (23) (18) Natural Gas MMBtu 17 — Interest Dollars $ 2,467 $ 1,084 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, 2023 December 31, 2022 December 31, 2023 December 31, 2022 (In millions) Derivatives Designated as Cash Flow Hedges: Interest rate contracts current $ 7 $ 7 $ — $ — Interest rate contracts long-term 12 18 2 — Total Derivatives Designated as Cash Flow Hedges $ 19 $ 25 $ 2 $ — Derivatives Not Designated as Cash Flow Hedges: Interest rate contracts current $ 33 $ 19 $ — $ — Interest rate contracts long-term 69 45 — — Energy-related commodity contracts current 1 — 51 50 Energy-related commodity contracts long-term 1 — 279 303 Total Derivatives Not Designated as Cash Flow Hedges $ 104 $ 64 $ 330 $ 353 Total Derivatives $ 123 $ 89 $ 332 $ 353 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, 2023 and 2022, 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, 2023 Gross Amounts of Recognized Assets/Liabilities Derivative Instruments Net Amount Energy-related commodity contracts (In millions) Derivative assets $ 2 $ — $ 2 Derivative liabilities (330) — (330) Total energy-related commodity contracts $ (328) $ — $ (328) Interest rate contracts Derivative assets $ 121 $ (2) $ 119 Derivative liabilities (2) 2 — Total interest rate contracts $ 119 $ — $ 119 Total derivative instruments $ (209) $ — $ (209) Gross Amounts Not Offset in the Statement of Financial Position As of December 31, 2022 Gross Amounts of Recognized Assets/Liabilities Derivative Instruments Net Amount Energy-related commodity contracts (In millions) Derivative liabilities $ (353) $ — $ (353) Total energy-related commodity contracts $ (353) $ — $ (353) Interest rate contracts Derivative assets $ 89 $ — $ 89 Total interest rate contracts $ 89 $ — $ 89 Total derivative instruments $ (264) $ — $ (264) 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, net of tax: Year ended December 31, 2023 2022 2021 (In millions) Accumulated OCI (OCL) beginning balance $ 24 $ (11) $ (30) Reclassified from accumulated OCI (OCL) to income due to realization of previously deferred amounts (4) 4 8 Capistrano Wind Portfolio Acquisition (a) — 7 — Mark-to-market of cash flow hedge accounting contracts (2) 24 11 Accumulated OCI (OCL) ending balance, net of income tax expense (benefit) of $2, $3 and $(2), respectively 18 24 (11) Accumulated OCI (OCL) attributable to noncontrolling interests 11 15 (5) Accumulated OCI (OCL) attributable to Clearway Energy, Inc. $ 7 $ 9 $ (6) Income expected to be realized from OCI during the next 12 months, net of income tax expense of $1 $ 4 (a) Represents $4 million attributable to Clearway Energy, Inc. and $3 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 Income Mark-to-market gains/(losses) related to the Company’s derivatives are recorded in the consolidated statements of income as follows: Year ended December 31, 2023 2022 2021 (In millions) Interest Rate Contracts (Interest expense) $ (17) $ 100 $ 53 Energy-Related Commodity Contracts (Mark-to-market for economic hedging activities included in Total operating revenues) (a) 23 (174) (83) Energy-Related Commodity Contracts (Mark-to-market for economic hedging activities included in Cost of operations) (b) 2 — — (a) Relates to long-term energy-related commodity contracts at Elbow Creek, Mesquite Star, Mt. Storm, Langford and Mesquite Sky and short-term heat rate call option energy-related commodity contracts at El Segundo, Marsh Landing and Walnut Creek. During the year ended December 31, 2022, the energy-related commodity contract for Langford, which previously met the NPNS exception, no longer qualified for NPNS treatment and, accordingly, is accounted for as a derivative and marked to fair value through operating revenues. (b) Relates to long-term 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. |
Intangible Assets
Intangible Assets | 12 Months Ended |
Dec. 31, 2023 | |
Goodwill and Intangible Assets Disclosure [Abstract] | |
Intangible Assets | Intangible Assets Intangible Assets — The Company’s intangible assets as of December 31, 2023 and 2022 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, Walnut Creek, Tapestry, Laredo Ridge, Carlsbad Energy Center, Agua Caliente, the Utah Solar Portfolio and the Capistrano Wind Portfolio. 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 projects. 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 SO 2 and NO x 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 NO x allowances amortized on a straight-line basis and SO 2 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 projects; 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 Star Portfolio. The following tables summarize the components of intangible assets subject to amortization: Year ended December 31, 2023 PPAs Leasehold Rights Emission Allowances Other Total (In millions) January 1, 2023 $ 3,321 $ 86 $ 17 $ 18 $ 3,442 Walnut Creek PPA expiration (50) — — — (50) Other (6) — — (3) (9) December 31, 2023 3,265 86 17 15 3,383 Less accumulated amortization (962) (38) (4) (5) (1,009) Net carrying amount $ 2,303 $ 48 $ 13 $ 10 $ 2,374 Year ended December 31, 2022 PPAs Leasehold Rights Emission Other Total (In millions) January 1, 2022 $ 2,985 $ 86 $ 17 $ 16 $ 3,104 Acquisitions (a) 336 — — — 336 Other — — — 2 2 December 31, 2022 3,321 86 17 18 3,442 Less accumulated amortization (833) (34) (4) (6) (877) Net carrying amount $ 2,488 $ 52 $ 13 $ 12 $ 2,565 (a) The weighted average life of acquired intangibles was 10 years for PPAs. The Company recorded amortization expense of $186 million, $174 million and $143 million during the years ended December 31, 2023, 2022 and 2021, respectively. Of these amounts, $181 million, $168 million and $135 million during the years ended December 31, 2023, 2022 and 2021, respectively, were related to the amortization of intangible assets for power purchase agreements and were recorded to contract amortization expense, which reduced operating revenues in the consolidated statements of income. The Company estimates the future amortization expense for its intangibles for the next five years as follows: (In millions) 2024 $ 184 2025 184 2026 184 2027 183 2028 183 |
Asset Impairments
Asset Impairments | 12 Months Ended |
Dec. 31, 2023 | |
Goodwill and Intangible Assets Disclosure [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 projects within the Renewables 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. 2022 Impairment Losses The impairment analysis indicated that the projected future cash flows for certain projects within the Renewables 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 $16 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. 2021 Impairment Losses The impairment analysis indicated that the projected future cash flows for several wind projects within the Renewables 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 $6 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. |
Long-term Debt
Long-term Debt | 12 Months Ended |
Dec. 31, 2023 | |
Debt Disclosure [Abstract] | |
Long-term Debt | Long-term Debt The Company’s borrowings, including short-term and long-term portions, consisted of the following: December 31, 2023 December 31, 2022 Interest rate % (a)(b) Letters of Credit Outstanding at December 31, 2023 (In millions, except rates) 2028 Senior Notes $ 850 $ 850 4.750 2031 Senior Notes 925 925 3.750 2032 Senior Notes 350 350 3.750 Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 (b) — — S+1.850 $ 246 Non-recourse project-level debt: — Agua Caliente Solar LLC, due 2037 612 649 2.395-3.633 45 Alta Wind Asset Management LLC, due 2031 11 12 S+2.775 — Alta Wind I-V lease financing arrangements, due 2034 and 2035 660 709 5.696-7.015 67 Alta Wind Realty Investments LLC, due 2031 20 22 7.000 — Borrego, due 2024 and 2038 48 51 Various 4 Broken Bow, due 2031 41 45 S+2.100 6 Buckthorn Solar, due 2025 116 119 S+2.100 20 Carlsbad Energy Holdings LLC, due 2027 93 115 S+1.900 63 Carlsbad Energy Holdings LLC, due 2038 407 407 4.120 — Carlsbad Holdco, LLC, due 2038 195 197 4.210 5 Cedro Hill, due 2024 and 2029 165 82 S+1.375 — Crofton Bluffs, due 2031 27 29 S+2.100 3 CVSR, due 2037 601 627 2.339-3.775 — CVSR Holdco Notes, due 2037 152 160 4.680 12 Daggett 2, due 2028 156 — S+1.762 36 Daggett 3, due 2028 217 — S+1.762 43 DG-CS Master Borrower LLC, due 2040 385 413 3.510 30 Mililani I, due 2027 (c) — 47 S+1.600 — Mililani Class B Member Holdco LLC, due 2028 (c) 92 — S+1.600 18 NIMH Solar, due 2024 148 163 S+2.275 10 Oahu Solar Holdings LLC, due 2026 81 83 S+1.525 9 Rosie Class B LLC, due 2024 and 2029 347 76 S+1.250-1.375 24 Texas Solar Nova 1, due 2028 102 — S+1.750 55 Utah Solar Portfolio, due 2036 242 257 3.590 155 Viento Funding II, LLC, due 2029 175 184 S+1.475 25 Victory Pass and Arica, due 2024 757 — S+1.125 5 Waiawa, due 2028 (c) — 97 S+1.600 — Other 124 201 Various 63 Subtotal non-recourse project-level debt 5,974 4,745 Total debt 8,099 6,870 Less current maturities (558) (322) Less net debt issuance costs (65) (61) Add premiums (d) 3 4 Total long-term debt $ 7,479 $ 6,491 (a) As of December 31, 2023, S+ equals SOFR plus x%. (b) Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement. (c) On July 21, 2023, Mililani I’s financing agreement was amended to merge the project-level debt of Mililani I and Waiawa as a combined term loan under Mililani Class B Member Holdco LLC. (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 the respective arrangement. Under the project-level financing arrangements, each project 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 project is otherwise in compliance with all relevant conditions under the financing agreements, including meeting required financial ratios, where applicable. The Company’s project-level financing arrangements are non-recourse to the Company, thus, each project pledges its underlying assets as collateral, and if a project is in default of its financing arrangement, then the related lender could demand repayment of the project or enforce their security interests with respect to the pledged collateral. As of December 31, 2023, the Company was in compliance with all of the required covenants. Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility On March 15, 2023, Clearway Energy Operating LLC refinanced the Amended and Restated Credit Agreement, which (i) replaced LIBOR with SOFR plus a credit spread adjustment of 0.10% as the applicable reference rate, (ii) increased the available revolving commitments to an aggregate principal amount of $700 million, (iii) extended the maturity date to March 15, 2028, (iv) increased the letter of credit sublimit to $594 million and (v) implemented certain other technical modifications. As of December 31, 2023, the Company had no outstanding borrowings under the revolving credit facility and $246 million in letters of credit outstanding. The facility will continue to be used for general corporate purposes, including financing of future acquisitions and posting letters of credit. Bridge Loan Agreement On November 30, 2021, Clearway Energy Operating LLC entered into a senior secured bridge credit agreement, or the Bridge Loan Agreement. The Bridge Loan Agreement provided for a senior secured term loan facility in an aggregate principal amount of $335 million. The borrowings under the term loan facility were used to acquire the Utah Solar Portfolio on December 1, 2021 . On May 3, 2022, the Company repaid the $335 million in outstanding borrowings under the Bridge Loan Agreement utilizing proceeds received from the Thermal Disposition, as further described in Note 3, Acquisitions and Dispositions . Project-level Debt Texas Solar Nova 1 On December 28, 2023, as part of the acquisition of Texas Solar Nova 1, as further described in Note 3, Acquisitions and Dispositions , the Company assumed the project’s financing agreement, which included a $90 million construction loan, $109 million sponsor 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 cash equity investor, to repay the $109 million sponsor equity bridge loan, to repay the $151 million tax equity bridge loan, to fund $18 million in construction completion reserves, which is 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. 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 sponsor equity bridge loan, related to the repowering of the Cedro Hill wind project. 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 is 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 is included in other non-current assets on the Company’s 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. 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 project’s financing agreement, which included a $483 million sponsor 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 sponsor 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 cash equity investor. The tax equity bridge loan and the remaining sponsor equity bridge loan will be repaid with the final proceeds received from the tax equity investor and cash equity investor upon Victory Pass and Arica reaching substantial completion, which is expected to occur in the first half of 2024, along with the $100 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, the Company borrowed an additional $22 million in tax equity bridge loans. Daggett 2 On August 30, 2023, as part of the acquisition of Daggett 2, as further described in Note 3, Acquisitions and Dispositions , the Company assumed the project’s financing agreement, which included a $107 million construction loan and a $204 million tax equity bridge loan, offset by $3 million in unamortized debt issuance costs. On December 22, 2023, when the project reached substantial completion, the tax equity investor contributed an additional $202 million, which was utilized, along with the $120 million in escrow and $10 million in construction loan proceeds, to repay the $204 million tax equity bridge loan, to fund $36 million in construction completion reserves, which is included in restricted cash on the Company’s consolidated balance sheet, and to pay $1 million in associated fees with the remaining $91 million distributed to CEG. Subsequent to the acquisition, the Company borrowed an additional $49 million in construction loans and the total outstanding construction loans were converted to a term loan in the amount of $156 million on December 22, 2023. Rosamond Central (Rosie Class B LLC) On June 30, 2023, Rosie Class B LLC, the indirect owner of the Rosamond Central solar project, 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, which will convert to a term loan upon the BESS project reaching substantial completion, (iii) tax equity bridge loans up to $188 million, which will be repaid with tax equity proceeds received upon the BESS project reaching substantial completion, (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 five years subsequent to term conversions. During the year ended December 31, 2023, Rosie Class B LLC received total loan proceeds of $265 million, which was comprised of $115 million in construction loans and $155 million in tax equity bridge loans, net of $5 million in debt issuance costs that were deferred. 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 project. On December 1, 2023, the Rosamond Central solar project acquired the BESS project from Clearway Renew for initial cash consideration of $70 million, as further discussed in Note 3, Acquisitions and Dispositions , and Clearway Renew utilized the funds to partially repay the loan. As of December 31, 2023, the loan had an aggregate principal amount of $174 million. The loan bears interest at a fixed annual rate of 9.00% and matures when the project reaches substantial completion, which is expected to occur in the first half of 2024 and is included in note receivable — affiliate on the Company’s consolidated balance sheet. Also, during the year ended December 31, 2023, the Company utilized a portion of the loan proceeds received under the amended financing agreement to contribute $18 million into Rosie Central BESS, which is an investment accounted for under the equity method of accounting, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities . Daggett 3 On February 17, 2023, as part of the acquisition of Daggett 3, as further described in Note 3, Acquisitions and Dispositions , the Company assumed the project’s financing agreement, which included a $181 million construction loan, a $229 million tax equity bridge loan and a $75 million sponsor equity bridge loan, offset by $5 million in unamortized debt issuance costs. The sponsor equity bridge loan was repaid at acquisition date, along with $8 million in associated fees, utilizing all of the proceeds from the Company, which were contributed back to the Company by CEG, and the contribution from the cash equity investor. On December 1, 2023, when the project reached substantial completion, the tax equity investor contributed an additional $252 million, which was utilized along with the $69 million in escrow, to repay the $229 million tax equity bridge loan, to fund $40 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 $45 million distributed to CEG. Subsequent to the acquisition, the Company borrowed an additional $36 million in construction loans and the total outstanding construction loans were converted to a term loan in the amount of $217 million on December 1, 2023. El Segundo Energy Center On December 15, 2022, the Company repaid the outstanding project-level debt of El Segundo Energy Center in the amount of approximately $130 million, utilizing cash on hand. The project-level debt had an original maturity of August 2023. Capistrano Wind Portfolio On August 22, 2022, as part of the acquisition of the Capistrano Wind Portfolio, as further described in Note 3, Acquisitions and Dispositions , the Company assumed non-recourse project-level debt totaling $164 million held by the Broken Bow, Cedro Hill and Crofton Bluffs wind projects, which is net of $2 million in previously deferred unamortized debt issuance costs. As discussed above, in connection with the Company’s entry into a new financing agreement related to the repowering of the Cedro Hill wind project, the Company repaid $72 million of outstanding principal under the original financing agreement. Mililani I and Waiawa On October 3, 2022, as part of the acquisition of Waiawa, as further described in Note 3, Acquisitions and Dispositions , the Company assumed the project’s financing agreement, which included a $22 million construction loan, a $55 million tax equity bridge loan and a $27 million sponsor equity bridge loan, offset by $1 million in unamortized debt issuance costs. The sponsor equity bridge loan was repaid at acquisition date, along with $2 million in associated fees, utilizing $12 million from the cash equity investor, as well as $16 million of the Company’s purchase price, which was contributed back by CEG. On March 30, 2023, when the project reached substantial completion, the tax equity investor contributed an additional $41 million and CEG contributed an additional $8 million, which was utilized, along with the $17 million in escrow, to repay the $55 million tax equity bridge loan, to fund $10 million in construction completion reserves and to pay $1 million in associated fees. Subsequent to the acquisition, the Company borrowed an additional $25 million in construction loans and the total outstanding construction loans were converted to a term loan in the amount of $47 million on March 30, 2023. On March 25, 2022, as part of the acquisition of Mililani I, as further described in Note 3, Acquisitions and Dispositions , the Company assumed the project’s financing agreement, which included a $16 million construction loan, a $60 million tax equity bridge loan and a $27 million sponsor equity bridge loan, offset by $3 million in unamortized debt issuance costs. The sponsor equity bridge loan was repaid at acquisition date, along with $2 million in associated fees, utilizing $14 million from the cash equity investor, as well as $15 million of the Company’s purchase price, which was contributed back by CEG. On December 7, 2022, when the project reached substantial completion, the tax equity investor contributed an additional $42 million and CEG contributed an additional $11 million, which was utilized, along with the $18 million in escrow, to repay the $60 million tax equity bridge loan, to fund $7 million in construction completion reserves and to pay $4 million in associated fees. Subsequent to the acquisition, the Company borrowed an additional $32 million in construction loans and the total outstanding construction loans were converted to a term loan in the amount of $48 million on December 7, 2022. On July 21, 2023, Mililani I’s financing agreement was amended to merge the project-level debt of Mililani I and Waiawa as a combined term loan under Mililani Class B Member Holdco LLC that matures on July 21, 2028. Viento Funding II, LLC On March 16, 2022, the Company, through its indirect subsidiary, Viento Funding II, LLC, entered into a financing agreement which included the issuance of a $190 million term loan as well as $35 million in letters of credit, supported by the Company’s interests in the Elkhorn Ridge, Laredo Ridge, San Juan Mesa and Taloga wind projects. The proceeds from the term loan were used to pay off the existing debt in the amount of $186 million related to Laredo Ridge, Tapestry Wind LLC and Viento Funding II, LLC and to pay related financing costs. The Company recorded a loss on debt extinguishment of $2 million to expense unamortized debt issuance costs. Interest Rate Swaps — Project Financings Many of the Company’s project subsidiaries entered into interest rate swaps, intended to hedge the risks associated with interest rates on non-recourse project level debt. These swaps amortize in proportion to their respective loans and are floating for a fixed rate where the project 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 project 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 project level debt: % of Principal Fixed Interest Rate Floating Interest Rate Notional Amount at December 31, 2023 (In millions) Effective Date Maturity Date Avra Valley 85 % 2.20 % SOFR $ 29 March 31, 2023 January 31, 2031 Alta Wind Asset Management 100 % 2.22 % SOFR 11 May 22, 2013 May 15, 2031 Borrego 100 % 0.21 % SOFR 3 June 30, 2020 December 31, 2024 Broken Bow 90 % Various SOFR 37 Various Various Buckthorn Solar 80 % Various SOFR 93 February 28, 2018 December 31, 2041 Carlsbad Energy Holdings 100 % Various SOFR 93 Various September 30, 2027 Cedro Hill 86 % Various SOFR 142 December 12, 2023 Various Crofton Bluffs 90 % Various SOFR 24 Various Various Daggett 2 90 % 2.22 % SOFR 141 August 3, 2022 March 31, 2043 Daggett 3 86 % 1.91 % SOFR 186 Various September 30, 2043 Kansas South 75 % 1.93 % SOFR 12 June 28, 2013 December 31, 2030 Mililani Class B 98 % Various SOFR 90 Various Various NIMH Solar 100 % Various SOFR 148 September 30, 2020 Various Oahu Solar 96 % 2.47 % SOFR 77 November 30, 2019 October 31, 2040 Rosie Class B 53 % Various SOFR 182 Various Various South Trent 90 % Various SOFR 22 June 14, 2019 June 30, 2028 Texas Solar Nova 1 94 % 2.92 % SOFR 97 October 31, 2022 June 30, 2043 Viento Funding II 90 % 2.53 % SOFR 158 Various December 31, 2032 Victory Pass and Arica 122 % 4.18 % SOFR 922 November 30, 2022 January 31, 2024 Total $ 2,467 Annual Maturities Annual payments based on the maturities of the Company’s debt, for the years ending after December 31, 2023, are as follows: (In millions) 2024 (a) $ 1,669 2025 371 2026 351 2027 288 2028 1,662 Thereafter 3,758 Total $ 8,099 (a) At December 31, 2023, amount includes $1.11 billion of construction-related financings recorded in long-term debt on the Company’s consolidated balance sheet that is due in 2024 and is either being funded through long-term equity contributions or is converting to long-term debt. |
Earnings Per Share
Earnings Per Share | 12 Months Ended |
Dec. 31, 2023 | |
Earnings Per Share [Abstract] | |
Earnings Per Share | Earnings Per Share Basic earnings per common share is computed by dividing net income by the weighted average number of common shares outstanding. Shares issued during the year are weighted for the portion of the year that they were outstanding. Diluted earnings per share is computed in a manner consistent with that of basic earnings per share while giving effect to all potentially dilutive common shares that were outstanding during the period. The reconciliation of the Company’s basic and diluted earnings per share is shown in the following table: Year Ended December 31, 2023 2022 2021 (In millions, except per share data) (a) Common Class A Common Class C Common Class A Common Class C Common Class A Common Class C Basic and diluted income per share attributable to Clearway Energy, Inc. common stockholders Net income attributable to Clearway Energy, Inc. $ 23 $ 56 $ 172 $ 410 $ 15 $ 36 Weighted average number of common shares outstanding — basic and diluted 35 82 35 82 35 82 Earnings per weighted average common share — basic and diluted $ 0.67 $ 0.67 $ 4.99 $ 4.99 $ 0.44 $ 0.44 (a) |
Stockholders' Equity
Stockholders' Equity | 12 Months Ended |
Dec. 31, 2023 | |
Equity, Attributable to Parent [Abstract] | |
Stockholders' Equity | Stockholders’ Equity At-the-Market Equity Offering Program, or the ATM Program Under the Company’s ATM Program, the Company may offer and sell shares of its Class C common stock from time to time up to an aggregate sales price of $150 million through an at-the-market equity offering program, or the ATM Program. During the years ended December 31, 2023, 2022 and 2021, the Company did not sell any Class C common stock shares under the ATM Program. As of December 31, 2023, approximately $126 million of Class C common stock remains available for issuance under the ATM Program. Dividends to Class A and Class C common stockholders The following table lists the dividends paid on the Company’s Class A and Class C common stock during the year ended December 31, 2023: Fourth Quarter 2023 Third Quarter 2023 Second Quarter 2023 First Quarter 2023 Dividends per Class A share $ 0.3964 $ 0.3891 $ 0.3818 $ 0.3745 Dividends per Class C share 0.3964 0.3891 0.3818 0.3745 Dividends on the Class A and Class C common stock are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations. The Company expects that, based on current circumstances, comparable cash dividends will continue to be paid in the foreseeable future. On February 14, 2024, the Company declared a quarterly dividend on its Class A and Class C common stock of $0.4033 per share payable on March 15, 2024 to stockholders of record as of March 1, 2024. The Company has also authorized 10,000,000 shares of preferred stock, par value $0.01 per share. None of the shares of preferred stock have been issued. Distributions to CEG The following table lists the distributions paid to CEG during the year ended December 31, 2023 on Clearway Energy LLC’s Class B and D units: Fourth Quarter 2023 Third Quarter 2023 Second Quarter 2023 First Quarter 2023 Distributions per Class B unit $ 0.3964 $ 0.3891 $ 0.3818 $ 0.3745 Distributions per Class D unit 0.3964 0.3891 0.3818 0.3745 In addition to the quarterly distributions paid to CEG, Clearway Energy LLC distributed an additional $21 million to CEG during the year ended December 31, 2023, which represents CEG’s pro-rata share of distributions that were paid in order for the Company to make certain additional tax payments primarily associated with the sale of the Thermal Business. The Company’s share of the distribution was $30 million. The portion of the distributions paid by Clearway Energy LLC to CEG is recorded as a reduction to the Company’s noncontrolling interest balance. The portion of the distributions paid by Clearway Energy LLC to the Company was utilized to fund the dividends to the Class A and Class C common stockholders described above. On February 14, 2024, Clearway Energy LLC declared a quarterly distribution on its Class B and Class D units of $0.4033 per unit payable to CEG on March 15, 2024. |
Segment Reporting
Segment Reporting | 12 Months Ended |
Dec. 31, 2023 | |
Segment Reporting [Abstract] | |
Segment Reporting | Segment Reporting The Company’s segment structure reflects how management currently operates and allocates resources. The Company’s businesses are segregated based on conventional power generation and renewable businesses, which consist of solar, wind and energy storage. 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 operational measures including adjusted earnings before interest, taxes, depreciation and amortization, or Adjusted EBITDA and CAFD, as well as net income (loss). Approximately 50% of the Company’s operating revenues and 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, 2023, 2022 and 2021: 2023 2022 2021 Customer Conventional Renewables Conventional Renewables Conventional Renewables SCE 11% 13% 17% 17% 17% 16% PG&E 4% 13% 10% 15% 10% 13% Year ended December 31, 2023 (In millions) Conventional Generation Renewables 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 — — 36 36 Transaction and integration costs — — 4 4 Operating income (loss) 137 164 (38) 263 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) (111) (16) Income tax (benefit) expense — (2) — (2) Net Income (Loss) 109 (12) (111) (14) Net Income (Loss) Attributable to Clearway Energy, Inc. $ 109 $ 150 $ (180) $ 79 Balance Sheet Equity investments in affiliates $ 79 $ 281 $ — $ 360 Capital expenditures (b) 11 146 — 157 Total Assets $ 2,058 $ 12,205 $ 438 $ 14,701 (a) Includes eliminations. (b) Includes accruals. Year ended December 31, 2022 (In millions) Conventional Generation Renewables Thermal Corporate (a) Total Operating revenues $ 417 $ 696 $ 77 $ — $ 1,190 Cost of operations, exclusive of depreciation, amortization and accretion shown separately below 89 298 50 (2) 435 Depreciation, amortization and accretion 131 381 — — 512 Impairment losses — 16 — — 16 General and administrative — — 2 38 40 Transaction and integration costs — — — 7 7 Development costs — — 2 — 2 Total operating costs and expenses 220 695 54 43 1,012 Gain on sale of business — — — 1,292 1,292 Operating income 197 1 23 1,249 1,470 Equity in earnings of unconsolidated affiliates 3 26 — — 29 Other income, net 1 6 — 10 17 Loss on debt extinguishment — (2) — — (2) Interest expense (40) (87) (6) (99) (232) Income (loss) before income taxes 161 (56) 17 1,160 1,282 Income tax expense — 2 — 220 222 Net Income (Loss) 161 (58) 17 940 1,060 Net Income Attributable to Clearway Energy, Inc. $ 161 $ 49 $ 17 $ 355 $ 582 Balance Sheet Equity investments in affiliates $ 82 $ 282 $ — $ — $ 364 Capital expenditures (b)(c) 11 33 11 1 56 Total Assets $ 2,251 $ 9,515 $ — $ 546 $ 12,312 (a) Includes eliminations. (b) Includes accruals. (c) Thermal capital expenditures, including accruals, prior to the sale of the Thermal Business on May 1, 2022. Year ended December 31, 2021 (In millions) Conventional Generation Renewables Thermal Corporate (a) Total Operating revenues $ 441 $ 641 $ 204 $ — $ 1,286 Cost of operations, exclusive of depreciation, amortization and accretion shown separately below 90 229 134 (2) 451 Depreciation, amortization and accretion 132 354 23 — 509 Impairment losses — 6 — — 6 General and administrative — — 4 36 40 Transaction and integration costs — — — 7 7 Development costs — — 4 2 6 Operating income (loss) 219 52 39 (43) 267 Equity in earnings of unconsolidated affiliates 6 26 — — 32 Other income, net — 2 1 — 3 Loss on debt extinguishment — (1) — (52) (53) Interest expense (53) (142) (18) (99) (312) Income (loss) before income taxes 172 (63) 22 (194) (63) Income tax expense — 2 — 10 12 Net Income (Loss) 172 (65) 22 (204) (75) Net Income (Loss) Attributable to Clearway Energy, Inc. $ 172 $ 109 $ 22 $ (252) $ 51 (a) Includes eliminations. |
Income Taxes
Income Taxes | 12 Months Ended |
Dec. 31, 2023 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | Income Taxes Effective Tax Rate The income tax provision consisted of the following amounts: Year Ended December 31, 2023 2022 2021 (In millions) Current U.S. Federal $ (13) $ — $ — State (2) 28 — Total — current (15) 28 — Deferred U.S. Federal $ 13 $ 150 $ (2) State — 44 14 Total — deferred 13 194 12 Total income tax (benefit) expense $ (2) $ 222 $ 12 A reconciliation of the U.S. federal statutory rate of 21% to the Company’s effective rate is as follows: Year Ended December 31, 2023 2022 2021 (In millions, except percentages) (Loss) Income Before Income Taxes $ (16) $ 1,282 $ (63) Tax at 21% (3) 269 (13) State taxes, net of federal benefit (2) 58 (4) Impact of non-taxable partnership earnings (losses) 21 (101) 34 Valuation allowance 3 — (14) Investment tax credits (1) — — Production tax credits (a) (16) (2) (1) Rate change 1 (2) (2) Partnership state basis — — 8 State taxes assessed at subsidiaries (3) 2 2 Other (2) (2) 2 Income tax (benefit) expense $ (2) $ 222 $ 12 Effective income tax rate 12.5 % 17.3 % (19.0) % (a) On December 6, 2023, the Company executed an agreement with a third party to sell the PTCs generated by the Alta X and Alta XI wind projects, which resulted in a $14 million income tax benefit (reduction to income tax expense) during the year ended December 31, 2023. For the year ended December 31, 2023, the overall effective tax rate was different than the statutory rate of 21% primarily due to the allocation of taxable earnings and losses based on the partners’ interest in Clearway Energy LLC, which includes the effects of applying the HLBV method of accounting for book purposes for certain partnerships, partially offset by the impact of PTCs generated. For the year ended December 31, 2022, the overall effective tax rate was different than the statutory rate of 21% primarily due to the allocation of taxable earnings and losses, including the gain on the sale of the Thermal Business, based on the partners’ interest in Clearway Energy LLC, which includes the effects of applying the HLBV method of accounting for book purposes for certain partnerships. For the year ended December 31, 2021, the overall effective tax rate was different than the statutory rate of 21% primarily due to the allocation of taxable earnings and losses based on the partners’ interest in Clearway Energy LLC, which includes the effects of applying the HLBV method of accounting for book purposes for certain partnerships. For tax purposes, Clearway Energy LLC is treated as a partnership; therefore, the Company and CEG each record their respective share of taxable income or loss. The temporary differences, which gave rise to the Company’s deferred tax balances consisted of the following: As of December 31, 2023 2022 (In millions) Deferred tax liabilities: Investment in projects $ 241 $ 240 Total deferred tax liabilities 241 240 Deferred tax assets: Interest expense disallowance carryforward - Investment in Projects $ 17 $ — Production tax credits 15 13 Investment tax credits 6 5 U.S. Federal net operating loss carryforwards 73 100 State net operating loss carryforwards 7 4 Total deferred tax assets 118 122 Valuation allowance (4) (1) Total deferred tax assets, net of valuation allowance 114 121 Net deferred non-current tax liability $ (127) $ (119) Tax Receivable As of December 31, 2023, the Company has a $13 million tax receivable. Deferred Tax Balances and Valuation Allowance Net deferred tax balances — As of December 31, 2023 and 2022, the Company recorded a net deferred tax liability of $127 million and $119 million, respectively. The Company believes it is more likely than not that the results of future operations will generate sufficient taxable income, which includes the future reversal of existing taxable temporary differences to realize deferred tax assets. The Company considered the profit before tax generated in recent years as well as projections of future earnings and estimates of taxable income in arriving at this conclusion. The Company believes that $4 million of existing state NOLs, based on forecasted future earnings and estimated taxable income, will expire unutilized, resulting in the recording of a valuation allowance. NOL and Tax Credit carryforwards — As of December 31, 2023, the Company had tax-effected domestic NOL carryforwards for federal income tax purposes of $73 million. Additionally, the Company has a cumulative tax-effected state NOL carryforward of $7 million, which will expire between 2024 and 2040 if unutilized. In addition, the Company has PTC and ITC carryforward balances totaling $21 million, which will expire between 2035 and 2043 if unutilized. Uncertain Tax Positions |
Related Party Transactions
Related Party Transactions | 12 Months Ended |
Dec. 31, 2023 | |
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 project entities. 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. 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 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 $73 million, $71 million and $56 million for the years ended December 31, 2023, 2022 and 2021, respectively. There was a balance of $13 million and $14 million due to RENOM as of December 31, 2023 and 2022, 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 $20 million, $16 million and $14 million for the years ended December 31, 2023, 2022 and 2021, respectively. There was a balance of $2 million and $3 million due to CEG as of December 31, 2023 and 2022, respectively. CEG Master Services Agreements The Company is a party to the CEG Master Services Agreements, 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 the Company provides certain services to CEG, including accounting, internal audit, tax and treasury services, in exchange for the payment of fees in respect of such services. The Company incurred net expenses of $5 million under these agreements for each of the years ended December 31, 2023 and 2022 and $4 million for the year ended December 31, 2021. |
Commitments and Contingencies
Commitments and Contingencies | 12 Months Ended |
Dec. 31, 2023 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | Commitments and Contingencies Gas and Transportation Commitments The Company previously entered into contractual arrangements to procure power, fuel and associated transportation services for the Thermal Business, which was sold to KKR on May 1, 2022, as further discussed in Note 3, Acquisitions and Dispositions . Under these arrangements, the Company purchased $20 million and $40 million for the years ended December 31, 2022 and 2021, respectively. 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. Buckthorn Solar Litigation On October 8, 2019, the City of Georgetown, Texas, or Georgetown, filed a petition in the District Court of Williamson County, Texas naming Buckthorn Westex, LLC, the Company’s subsidiary that owns the Buckthorn Westex solar project, as the defendant, alleging fraud by nondisclosure and breach of contract in connection with the project and the PPA, and seeking (i) rescission and/or cancellation of the PPA, (ii) declaratory judgment that the alleged breaches constitute an event of default under the PPA entitling Georgetown to terminate, and (iii) recovery of all damages, costs of court, and attorneys’ fees. On November 15, 2019, Buckthorn Westex filed an original answer and counterclaims (i) denying Georgetown’s claims, (ii) alleging Georgetown has breached its contracts with Buckthorn Westex by failing to pay amounts due, and (iii) seeking relief in the form of (x) declaratory judgment that Georgetown’s alleged failure to pay amounts due constitute breaches of and an event of default under the PPA and that Buckthorn did not commit any events of default under the PPA, (y) recovery of costs, expenses, interest, and attorneys’ fees, and (z) such other relief to which it is entitled at law or in equity. On November 14, 2023, the two parties entered into a settlement agreement to resolve all claims related to this litigation, following which settlement the claims were dismissed by the court with prejudice. The amounts paid pursuant to the settlement agreement had an immaterial impact to the Company’s financial statements. |
Leases
Leases | 12 Months Ended |
Dec. 31, 2023 | |
Leases [Abstract] | |
Leases | 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) 2023 2022 2021 Operating lease cost - Fixed $ 40 $ 36 $ 27 Operating lease cost - Variable 11 11 15 Total lease cost $ 51 $ 47 $ 42 Operating lease information was as follows: (In millions, except term and rate) December 31, 2023 December 31, 2022 Right-of-use assets - operating leases, net (a) $ 597 $ 527 Short-term lease liability - operating leases (b) $ 7 $ 6 Long-term lease liability - operating leases (a) 627 548 Total lease liabilities $ 634 $ 554 Weighted average remaining lease term (in years) 28 27 Weighted average discount rate 4.2 % 4.1 % Cash paid for operating leases $ 30 $ 28 (a) Increases in right-of-use assets and long-term lease liabilities are primarily due to Drop Down Asset 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, 2023 and 2022. Minimum future rental payments of operating lease liabilities as of December 31, 2023 are as follows: (In millions) 2024 $ 34 2025 34 2026 35 2027 36 2028 36 Thereafter 980 Total lease payments 1,155 Less imputed interest (521) Total lease liability - operating leases $ 634 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, 2023 Daggett 2 $ 22 $ 23 June 30, 2058 Daggett 3 31 33 December 18, 2062 Mililani I 19 20 March 31, 2057 Oahu Solar (a) 17 20 August 1, 2057 Rosamond Central (a) 11 12 March 31, 2056 As of December 31, 2022 Mililani I $ 19 $ 20 Oahu Solar (a) 17 20 Rosamond Central (a) 11 12 (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. The terms of the Company’s leases are further described in Item 2 — Properties of this Form 10-K. 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 revenue are related to the Company’s operating leases: Conventional Generation Renewables Total December 31, 2023 (In millions) Energy revenue $ 4 $ 760 $ 764 Capacity revenue 249 20 269 Other revenue (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 will receive 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. Conventional Generation Renewables Thermal Total December 31, 2022 (In millions) Energy revenue $ 6 $ 809 $ 1 $ 816 Capacity revenue 435 — — 435 Operating revenues $ 441 $ 809 $ 1 $ 1,251 Conventional Generation Renewables Thermal Total December 31, 2021 (In millions) Energy revenue $ 9 $ 716 $ 2 $ 727 Capacity revenue 455 — — 455 Operating revenues $ 464 $ 716 $ 2 $ 1,182 Minimum future rent payments for the remaining periods related to the Company’s operating leases as of December 31, 2023 were as follows: (In millions) 2024 $ 146 2025 147 2026 148 2027 149 2028 150 Thereafter 1,635 Total lease payments $ 2,375 Property, plant and equipment, net related to the Company’s operating leases were as follows: (In millions) December 31, 2023 December 31, 2022 Property, plant and equipment $ 5,720 $ 8,630 Accumulated depreciation (1,991) (2,855) Net property, plant and equipment $ 3,729 $ 5,775 |
Leases | 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) 2023 2022 2021 Operating lease cost - Fixed $ 40 $ 36 $ 27 Operating lease cost - Variable 11 11 15 Total lease cost $ 51 $ 47 $ 42 Operating lease information was as follows: (In millions, except term and rate) December 31, 2023 December 31, 2022 Right-of-use assets - operating leases, net (a) $ 597 $ 527 Short-term lease liability - operating leases (b) $ 7 $ 6 Long-term lease liability - operating leases (a) 627 548 Total lease liabilities $ 634 $ 554 Weighted average remaining lease term (in years) 28 27 Weighted average discount rate 4.2 % 4.1 % Cash paid for operating leases $ 30 $ 28 (a) Increases in right-of-use assets and long-term lease liabilities are primarily due to Drop Down Asset 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, 2023 and 2022. Minimum future rental payments of operating lease liabilities as of December 31, 2023 are as follows: (In millions) 2024 $ 34 2025 34 2026 35 2027 36 2028 36 Thereafter 980 Total lease payments 1,155 Less imputed interest (521) Total lease liability - operating leases $ 634 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, 2023 Daggett 2 $ 22 $ 23 June 30, 2058 Daggett 3 31 33 December 18, 2062 Mililani I 19 20 March 31, 2057 Oahu Solar (a) 17 20 August 1, 2057 Rosamond Central (a) 11 12 March 31, 2056 As of December 31, 2022 Mililani I $ 19 $ 20 Oahu Solar (a) 17 20 Rosamond Central (a) 11 12 (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. The terms of the Company’s leases are further described in Item 2 — Properties of this Form 10-K. 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 revenue are related to the Company’s operating leases: Conventional Generation Renewables Total December 31, 2023 (In millions) Energy revenue $ 4 $ 760 $ 764 Capacity revenue 249 20 269 Other revenue (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 will receive 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. Conventional Generation Renewables Thermal Total December 31, 2022 (In millions) Energy revenue $ 6 $ 809 $ 1 $ 816 Capacity revenue 435 — — 435 Operating revenues $ 441 $ 809 $ 1 $ 1,251 Conventional Generation Renewables Thermal Total December 31, 2021 (In millions) Energy revenue $ 9 $ 716 $ 2 $ 727 Capacity revenue 455 — — 455 Operating revenues $ 464 $ 716 $ 2 $ 1,182 Minimum future rent payments for the remaining periods related to the Company’s operating leases as of December 31, 2023 were as follows: (In millions) 2024 $ 146 2025 147 2026 148 2027 149 2028 150 Thereafter 1,635 Total lease payments $ 2,375 Property, plant and equipment, net related to the Company’s operating leases were as follows: (In millions) December 31, 2023 December 31, 2022 Property, plant and equipment $ 5,720 $ 8,630 Accumulated depreciation (1,991) (2,855) Net property, plant and equipment $ 3,729 $ 5,775 |
Schedule I - Condensed Financia
Schedule I - Condensed Financial Information of Registrant | 12 Months Ended |
Dec. 31, 2023 | |
Condensed Financial Information Disclosure [Abstract] | |
Condensed Financial Information of Registrant | Clearway Energy, Inc. (Parent) Condensed Financial Information of Registrant Condensed Statements of Income Year ended December 31, (In millions) 2023 2022 2021 Total operating costs and expenses $ 1 $ 2 $ 2 Equity in (losses) earnings of consolidated subsidiaries (13) 1,282 (63) Total other (expense) income, net (13) 1,282 (63) (Loss) Income Before Income Taxes (14) 1,280 (65) Income tax expense — 220 10 Net (Loss) Income (14) 1,060 (75) Less: Net (loss) income attributable to noncontrolling interests and redeemable noncontrolling interests (93) 478 (126) Net Income Attributable to Clearway Energy, Inc. $ 79 $ 582 $ 51 Clearway Energy, Inc. (Parent) Condensed Balance Sheets December 31, December 31, 2023 2022 ASSETS (In millions) Current Assets Accounts receivable — affiliates $ 3 $ 2 Note receivable — Clearway Energy Operating LLC 1 2 Other current assets 13 — Other Assets Investment in consolidated subsidiaries 5,106 4,161 Total Assets $ 5,123 $ 4,165 LIABILITIES AND STOCKHOLDERS’ EQUITY Current Liabilities Other current liabilities $ — $ 19 Other Liabilities Deferred income taxes 125 115 Other non-current liabilities 4 5 Total Liabilities 129 139 Commitments and Contingencies Stockholders’ Equity Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued — — Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 202,080,794 shares issued and outstanding (Class A 34,613,853, Class B 42,738,750, Class C 82,391,441, Class D 42,336,750) at December 31, 2023 and 201,972,813 shares issued and outstanding (Class A 34,613,853, Class B 42,738,750, Class C 82,283,460, Class D 42,336,750) at December 31, 2022 1 1 Additional paid-in capital 1,732 1,761 Retained earnings 361 463 Accumulated other comprehensive income 7 9 Noncontrolling interest 2,893 1,792 Total Stockholders’ Equity 4,994 4,026 Total Liabilities and Stockholders’ Equity $ 5,123 $ 4,165 Clearway Energy, Inc. (Parent) Condensed Statements of Cash Flows Year ended December 31, 2023 2022 2021 (In millions) Net Cash Used in Operating Activities $ (31) $ (10) $ (2) Cash Flows from Investing Activities Investments in consolidated affiliates — — 2 Cash advances for notes receivable — affiliate — (4) (2) Cash received from notes receivable — affiliate 1 3 2 Net Cash Provided by (Used in) Investing Activities 1 (1) 2 Cash Flows from Financing Activities Cash received from Clearway Energy LLC for tax-related distributions 30 11 — Cash received from Clearway Energy LLC for the payment of dividends 180 167 155 Payment of dividends (180) (167) (155) Net Cash Provided by Financing Activities 30 11 — Net Change in Cash — — — Cash at Beginning of Period — — — Cash at End of Period $ — $ — $ — Background Clearway Energy, Inc., together with its consolidated subsidiaries, or the Company, is a publicly-traded 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 GIP and TotalEnergies through the portfolio company, Clearway Energy Group LLC, or CEG, which is equally owned by GIP and TotalEnergies. GIP is an independent infrastructure fund manager that makes equity and debt investments in infrastructure assets and businesses. TotalEnergies is a global multi-energy company. CEG is a leading developer of renewable energy infrastructure in the U.S. The Company is one of the largest renewable energy owners in the U.S. with approximately 6,000 net MW of installed wind, solar and energy storage projects. The Company’s approximately 8,500 net MW of assets includes approximately 2,500 net MW of environmentally-sound, highly efficient natural gas-fired generation facilities. Through this environmentally-sound, diversified and primarily contracted portfolio, the Company endeavors to provide its investors with stable and growing dividend income. The majority of the Company’s revenues are derived from long-term contractual arrangements for the output or capacity from these assets. The Company consolidates the results of Clearway Energy LLC through its controlling interest, with CEG’s interest shown as noncontrolling interest in the financial statements. The holders of the Company’s outstanding shares of Class A and Class C common stock are entitled to dividends as declared. CEG receives its distributions from Clearway Energy LLC through its ownership of Clearway Energy LLC Class B and Class D units. From time to time, CEG may also hold shares of the Company’s Class A and/or Class C common stock. As of December 31, 2023, the Company owned 57.90% of the economic interests of Clearway Energy LLC, with CEG owning 42.10% of the economic interests of Clearway Energy LLC. 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, Inc.’s subsidiaries exceed 25% of the consolidated net assets of Clearway Energy, Inc. 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, Inc. Note 2 — Long-Term Debt For a discussion of Clearway Energy, Inc.’s financing arrangements, see Note 10, Long-term Debt, to the Company’s consolidated financial statements. Note 3 — Commitments, Contingencies and Guarantees See Note 14, Income Taxes, and Note 16, Commitments and Contingencies, to the Company’s consolidated financial statements for a detailed discussion of Clearway Energy, Inc.’s commitments and contingencies. Note 4 — Dividends |
Schedule II VALUATION AND QUALI
Schedule II VALUATION AND QUALIFYING ACCOUNTS | 12 Months Ended |
Dec. 31, 2023 | |
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract] | |
SCHEDULE II VALUATION AND QUALIFYING ACCOUNTS | SCHEDULE II. VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2023, 2022, and 2021 (In millions) Balance at Charged to Charged to Balance at Income tax valuation allowance, deducted from deferred tax assets Year Ended December 31, 2023 $ 1 $ 3 $ — $ 4 Year Ended December 31, 2022 1 — — 1 Year Ended December 31, 2021 15 (14) — 1 |
Pay vs Performance Disclosure
Pay vs Performance Disclosure - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Pay vs Performance Disclosure | |||
Net income attributable to Clearway Energy, Inc. | $ 79 | $ 582 | $ 51 |
Insider Trading Arrangements
Insider Trading Arrangements | 3 Months Ended |
Dec. 31, 2023 | |
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 |
Summary of Significant Accoun_2
Summary of Significant Accounting Policies (Policies) | 12 Months Ended |
Dec. 31, 2023 | |
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 and Cash Equivalents | Cash, Cash Equivalents and Restricted Cash |
Restricted Cash | Restricted cash consists primarily of funds held to satisfy the requirements of certain debt agreements and funds held within the Company’s projects that are restricted in their use. |
Accounts Receivable — Trade and Allowance for Credit Losses | Accounts Receivable — Trade and Allowance for Credit Losses |
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 income. 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, 2023, 2022 and 2021 was $36 million, $2 million and $3 million, respectively. |
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 income. 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 |
Intangible Assets | Intangible Assets |
Revenue Recognition | 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. Conventional Generation Revenues The majority of the conventional energy plants commenced merchant operations during 2023 following the expiration of the PPAs. These facilities generate revenues from selling electricity and/or RA to the California Independent System Operator and to public utility and load serving entities, as the power is delivered at the interconnection point. Thermal Revenues On May 1, 2022, the Company completed the sale of 100% of its interests in the Thermal Business to KKR. For further details of the Thermal Disposition refer to Note 3, Acquisitions and Dispositions. Prior to the Thermal Disposition, steam and chilled water revenue was recognized as the Company transferred the product to the customer, based on customer usage as determined by meter readings taken at month-end. Some locations read customer meters throughout the month and recognized estimated revenue for the period between meter read date and month-end. For thermal contracts, the Company’s performance obligation to deliver steam and chilled water was satisfied over time and revenue was recognized based on the invoiced amount. The Thermal Business subsidiaries collected and remitted state and local taxes associated with sales to their customers, as required by governmental authorities. These taxes were presented on a net basis in the consolidated statements of income. 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 conventional energy plants is 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 conventional energy plants 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, 2023, 2022 and 2021 was $780 million, $850 million and $741 million, respectively. See Note 17, 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 often 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. |
Derivative 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 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 for conventional facilities. 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 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 would be immediately reclassified into earnings. If the derivative financial instrument is terminated, the effective portion of this derivative deferred in accumulated OCI 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 projects have only one customer. See Item 1A, Risk Factors, Risks Related to the Company’s Business, for a discussion on the Company’s dependence on major customers . 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 |
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 projects 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 |
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 840-40, 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. |
Income Taxes | Income Taxes The Company accounts for income taxes using the liability method in accordance with ASC 740, Income Taxes , or ASC 740, which requires that the Company use the asset and liability method of accounting for deferred income taxes and provide deferred income taxes for all significant temporary differences. The Company has two categories of income tax expense or benefit — current and deferred, as follows: • Current income tax expense or benefit consists solely of current taxes payable less applicable tax credits, and • Deferred income tax expense or benefit is the change in the net deferred income tax asset or liability, excluding amounts charged or credited to accumulated other comprehensive income (loss). The Company reports some of its revenues and expenses differently for financial statement purposes than for income tax return purposes, resulting in temporary and permanent differences between the Company’s financial statements and income tax returns. The tax effects of such temporary differences are recorded as either deferred income tax assets or deferred income tax liabilities in the Company’s consolidated balance sheets. The Company measures its deferred income tax assets and deferred income tax liabilities using income tax rates that are currently in effect. The Company believes it is more likely than not that the results of future operations will generate sufficient taxable income which includes the future reversal of existing taxable temporary differences to realize deferred tax assets, net of valuation allowances. In arriving at this conclusion to utilize projections of future profit before tax in its estimate of future taxable income, the Company considered the profit before tax generated in recent years. A valuation allowance is recorded to reduce the net deferred tax assets to an amount that is more-likely-than-not to be realized. The Company accounts for uncertain tax positions in accordance with ASC 740, which applies to all tax positions related to income taxes. Under ASC 740, tax benefits are recognized when it is more-likely-than-not that a tax position will be sustained upon examination by the authorities. The benefit recognized from a position that has surpassed the more-likely-than-not threshold is the largest amount of benefit that is more than 50% likely to be realized upon settlement. In accordance with ASC 740 and as discussed further in Note 14, Income Taxes , changes to existing net deferred tax assets, valuation allowances, or changes to uncertain tax benefits, are recorded to income tax expense. |
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 noncontrolling interest. |
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 certain tax equity arrangements, which are consolidated by the Company, that have been entered into to finance the cost of solar and wind facilities eligible for certain tax credits. The Company has determined that the provisions in the contractual agreements of these structures 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 income 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, tax provisions, 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. |
Reclassification | Reclassification Certain prior year amounts have been reclassified for comparative purposes. |
Recently Adopted Accounting Standards and Recent Accounting Standards Not Yet Adopted | Recently Adopted Accounting Standards In March 2020, the FASB issued ASU No. 2020-4, Facilitation of the Effects of Reference Rate Reform on Financial Reporting . The amendments provide for optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria are met. These amendments apply only to contracts that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform, which affects certain of the Company’s debt and interest rate swap agreements. The guidance is effective for all entities as of March 12, 2020 through December 31, 2022. In December 2022, the FASB issued ASU No. 2022-6, Deferral of the Sunset Date of Reference Rate Reform , to extend the end of the transition period to December 31, 2024. As of December 31, 2023, all of the applicable contracts that previously used LIBOR as a reference rate were amended and the Company elected to apply the practical expedient to certain modified cash flow interest rate swap and debt agreements. The adoption did not have a material impact on the Company’s financial statements. Recent Accounting Standards Not Yet Adopted In November 2023, the FASB issued ASU No. 2023-7, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures . The amendment improves reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expense categories and details regarding information utilized to assess segment performance. Additionally, the amendment increases the frequency of disclosures by requiring Topic 280 to be applied to interim financial statements. This guidance will be applied retrospectively and is effective for annual reporting periods in fiscal years beginning after December 15, 2023, and interim reporting periods in fiscal years beginning after December 31, 2024. As of December 31, 2023, 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 December 2023, the FASB issued ASU No. 2023-9, Income Taxes (Topic 740): Improvements to Income Tax Disclosures . The amendment improves income tax disclosure requirements requiring public entities, on an annual basis, to provide disclosure of defined categories in the income tax rate reconciliation, as well as disclosure of income taxes paid disaggregated by jurisdiction. This guidance will be applied prospectively and is effective for annual reporting periods in fiscal years beginning after December 15, 2024. As of December 31, 2023, the Company has not elected to early adopt the standard and is evaluating the effect of the new guidance on its consolidated financial statements. |
Nature of Business (Tables)
Nature of Business (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Company Structure | The diagram below represents a summarized structure of the Company as of December 31, 2023: |
Summary of Significant Accoun_3
Summary of Significant Accounting Policies (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
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, 2023 2022 (In millions) Cash and cash equivalents $ 535 $ 657 Restricted cash 516 339 Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 1,051 $ 996 |
Schedule of Restricted Cash | 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, 2023 2022 (In millions) Cash and cash equivalents $ 535 $ 657 Restricted cash 516 339 Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 1,051 $ 996 |
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, 2023 2022 2021 (In millions) Cash paid to acquire Drop Down Assets $ (173) $ (71) $ (230) Cash acquired from the acquisition of Drop Down Assets 128 — 1 Acquisition of Drop Down Assets, net of cash acquired $ (45) $ (71) $ (229) |
Summary 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, 2023 (In millions) Conventional Generation Renewables Total Energy revenue (a) $ 81 $ 942 $ 1,023 Capacity revenue (a) 336 23 359 Other revenue (a) 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 17, Leases, for the amounts of energy, capacity and other revenue that relate to leases and are accounted for under ASC 842. Year ended December 31, 2022 (In millions) Conventional Generation Renewables Thermal Total Energy revenue (a) $ 6 $ 956 $ 48 $ 1,010 Capacity revenue (a) 435 2 18 455 Other revenue — 71 11 82 Contract amortization (24) (151) — (175) Mark-to-market for economic hedges — (182) — (182) Total operating revenues 417 696 77 1,190 Less: Contract amortization 24 151 — 175 Less: Mark-to-market for economic hedges — 182 — 182 Less: Lease revenue (441) (809) (1) (1,251) Total revenue from contracts with customers $ — $ 220 $ 76 $ 296 (a) See Note 17, Leases , for the amounts of energy and capacity revenue that relate to leases and are accounted for under ASC 842. Year ended December 31, 2021 (In millions) Conventional Generation Renewables Thermal Total Energy revenue (a) $ 9 $ 784 $ 122 $ 915 Capacity revenue (a) 455 2 53 510 Other revenue — 60 32 92 Contract amortization (23) (118) (3) (144) Mark-to-market for economic hedges — (87) — (87) Total operating revenues 441 641 204 1,286 Less: Contract amortization 23 118 3 144 Less: Mark-to-market for economic hedges — 87 — 87 Less: Lease revenue (464) (716) (2) (1,182) Total revenue from contracts with customers $ — $ 130 $ 205 $ 335 (a) See Note 17, Leases , for the amounts of energy and capacity revenue that relate to leases and are accounted for under ASC 842. |
Schedule of Contract balances | The following table reflects the contract assets and liabilities included on the Company’s consolidated balance sheets: (In millions) December 31, 2023 December 31, 2022 Accounts receivable, net - Contracts with customers $ 66 $ 37 Accounts receivable, net - Leases 105 116 Total accounts receivable, net $ 171 $ 153 |
Schedule of Changes in Asset Retirement Obligation | The following table represents the balance of ARO obligations, along with the related activity: (In millions) Balance as of December 31, 2022 $ 157 Revisions in estimated cash flows 3 Liabilities incurred 67 Accretion expense 12 Balance as of December 31, 2023 $ 239 |
Schedule of Redeemable Noncontrolling Interest | The following table reflects the changes in the Company’s redeemable noncontrolling interest balance: (In millions) Balance at December 31, 2021 $ — Cash distributions to redeemable noncontrolling interests (4) Comprehensive income attributable to redeemable noncontrolling interests 11 Balance at December 31, 2022 7 Cash distributions to redeemable noncontrolling interests (3) Comprehensive income attributable to redeemable noncontrolling interests 17 Repurchase of redeemable noncontrolling interest (20) Balance at December 31, 2023 $ 1 |
Acquisitions and Dispositions (
Acquisitions and Dispositions (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Business Combination and Asset Acquisition [Abstract] | |
Schedule Of Asset Acquisition | The following is a summary of assets and liabilities transferred in connection with the acquisition as of December 28, 2023: (In millions) Texas Solar Nova 1 Cash $ 3 Property, plant and equipment 362 Right-of-use assets, net 21 Derivative assets 4 Other non-current assets 6 Total assets acquired 396 Long-term debt (a) 349 Long-term lease liabilities 19 Other current and non-current liabilities 34 Total liabilities assumed 402 Net liabilities assumed $ (6) (a) Includes a $90 million construction loan, $109 million sponsor equity bridge loan and $151 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 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 sponsor 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 August 30, 2023: (In millions) Daggett 2 Cash $ 1 Restricted cash (a) 119 Property, plant and equipment 379 Right-of-use assets, net 22 Derivative assets 22 Total assets acquired 543 Long-term debt (b) 308 Long-term lease liabilities 23 Other current and non-current liabilities 28 Total liabilities assumed 359 Noncontrolling interests 213 Net assets acquired less noncontrolling interests $ (29) (a) Includes funds that were contributed by the cash equity investor and tax equity investor, which were primarily used to pay off the tax equity bridge loan when the project reached substantial completion on December 22, 2023, as further discussed in Note 10, Long-term Debt . (b) Includes a $107 million construction loan and $204 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 February 17, 2023: (In millions) Daggett 3 Restricted cash $ 4 Property, plant and equipment 534 Right-of-use assets, net 31 Derivative assets 27 Total assets acquired 596 Long-term debt (a) 480 Long-term lease liabilities 33 Other current and non-current liabilities (b) 68 Total liabilities assumed 581 Net assets acquired $ 15 (a) Includes a $181 million construction loan, $75 million sponsor equity bridge loan and $229 million tax equity bridge loan, offset by $5 million in unamortized debt issuance costs. See Note 10, Long-term Debt , for further discussion of the long-term debt assumed in the acquisition. (b) Includes $32 million of project costs that were subsequently funded by CEG. Subsequent to the acquisition date, CEG funded an additional $22 million in project costs. The combined $54 million funded by CEG was repaid to CEG in October 2023. The following is a summary of assets and liabilities transferred in connection with the acquisition as of October 3, 2022: (In millions) Waiawa Other current and non-current assets $ 7 Property, plant and equipment 118 Total assets acquired 125 Long-term debt (a) 102 Other current and non-current liabilities 24 Total liabilities assumed 126 Net liabilities assumed $ (1) (a) Includes a $22 million construction loan, $26 million sponsor equity bridge loan and $55 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 following is a summary of assets and liabilities transferred in connection with the acquisition as of August 22, 2022: (In millions) Capistrano Wind Portfolio Other current and non-current assets (a) $ 39 Property, plant and equipment, net 147 Intangible assets for power purchase agreements 237 Right-of-use assets, net 27 Total assets acquired 450 Long-term debt 162 Long-term lease liabilities 28 Other current and non-current liabilities 10 Total liabilities assumed 200 Net assets acquired $ 250 (a) Includes cash of $12 million and restricted cash of $4 million. The following is a summary of assets and liabilities transferred in connection with the acquisition as of March 25, 2022: (In millions) Mililani I Other current and non-current assets $ 2 Property, plant and equipment 118 Right-of-use assets 19 Total assets acquired 139 Long-term debt (a) 100 Long-term lease liabilities 20 Other current and non-current liabilities 27 Total liabilities assumed 147 Net liabilities assumed $ (8) (a) Includes a $16 million construction loan, $27 million sponsor equity bridge loan and $60 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. |
Property, Plant and Equipment (
Property, Plant and Equipment (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
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, 2023 December 31, 2022 Depreciable Lives (In millions) Facilities and equipment $ 11,426 $ 9,992 3 - 41 Years Land and improvements 365 293 Construction in progress (a) (b) 1,220 160 Total property, plant and equipment 13,011 10,445 Accumulated depreciation (3,485) (3,024) Net property, plant and equipment $ 9,526 $ 7,421 (a) As of December 31, 2023 and 2022, construction in progress includes $21 million and $17 million, respectively, of capital expenditures that relate to prepaid long-term service agreements in the Conventional segment. (b) As of December 31, 2023 and 2022, construction in progress includes $72 million and $9 million, respectively, of accrued capital expenditures. |
Investments Accounted for by _2
Investments Accounted for by the Equity Method and Variable Interest Entities (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Equity Method Investments and Joint Ventures [Abstract] | |
Schedule of Equity Method Investments | The Company’s maximum exposure to loss as of December 31, 2023 is limited to its equity investment in the unconsolidated entities, as further summarized in the table below: Name Economic Interest Investment Balance (In millions) Avenal 50% $ 7 Desert Sunlight 25% 224 Elkhorn Ridge 66.7% 15 GenConn (a) 50% 79 Rosie Central BESS (a) 50% 28 San Juan Mesa 75% 7 $ 360 (a) GenConn and Rosie Central BESS are variable interest entities. The following tables present summarized financial information for the Company’s equity method investments: Year Ended December 31, 2023 2022 2021 Income Statement Data: (In millions) GenConn Operating revenues $ 51 $ 50 $ 55 Operating income 14 16 22 Net income 6 7 13 Desert Sunlight Operating revenues 202 203 205 Operating income 144 137 146 Net income 108 114 112 Other (a) Operating revenues 43 52 49 Operating income 9 18 16 Net income 7 15 13 As of December 31, 2023 2022 Balance Sheet Data: (In millions) GenConn Current assets $ 39 $ 39 Non-current assets 294 312 Current liabilities 15 16 Non-current liabilities 162 170 Desert Sunlight Current assets 80 79 Non-current assets 1,131 1,175 Current liabilities 61 61 Non-current liabilities 776 824 Other (a) Current assets 19 22 Non-current assets 135 157 Current liabilities 13 12 Non-current liabilities 81 91 (a) Includes Avenal, Elkhorn Ridge, San Juan Mesa and Rosie Central BESS. |
Schedule of Variable Interest Entities | Summarized financial information for the Company’s consolidated VIEs consisted of the following as of December 31, 2023: (In millions) Buckthorn Holdings, LLC DGPV Funds (a) Langford TE Partnership LLC Daggett Partnerships (b) Lighthouse Renewable Holdco LLC (c) Lighthouse Renewable Holdco 2 LLC (d) Other current and non-current assets $ 4 $ 58 $ 23 $ 167 $ 68 $ 135 Property, plant and equipment 185 381 115 988 415 1,086 Intangible assets — 1 — — — 2 Total assets 189 440 138 1,155 483 1,223 Current and non-current liabilities 12 50 63 464 139 447 Total liabilities 12 50 63 464 139 447 Noncontrolling interest 15 3 66 827 254 590 Net assets less noncontrolling interest $ 162 $ 387 $ 9 $ (136) $ 90 $ 186 (a) DGPV Funds is comprised of Clearway & EFS Distributed Solar LLC, Golden Puma Fund LLC, Renew Solar CS4 Fund LLC and Chestnut Fund LLC, which are all tax equity funds. (b) Daggett Partnerships includes Daggett 2 TargetCo LLC, which consolidates Daggett 2 TE Holdco LLC, a consolidated VIE, and Daggett Renewable Holdco LLC, which consolidates Daggett TE Holdco LLC, a consolidated VIE. (c) Lighthouse Renewable Holdco LLC consolidates Black Rock TE Holdco LLC and Mililani TE Holdco LLC, which are consolidated VIEs. (d) Lighthouse Renewable Holdco 2 LLC consolidates Mesquite Sky TE Holdco LLC, Mesquite Star Tax Equity Holdco LLC and TSN1 TE Holdco LLC, which are consolidated VIEs. (In millions) Oahu Solar LLC Rattlesnake TE Holdco LLC Rosie TargetCo LLC VP-Arica TargetCo LLC (a) Wildorado TE Holdco LLC Other (b) Other current and non-current assets $ 38 $ 13 $ 298 $ 101 $ 20 $ 24 Property, plant and equipment 157 176 507 960 194 238 Intangible assets — — — — — 16 Total assets 195 189 805 1,061 214 278 Current and non-current liabilities 22 17 376 834 18 85 Total liabilities 22 17 376 834 18 85 Noncontrolling interest 23 77 181 67 99 95 Net assets less noncontrolling interest $ 150 $ 95 $ 248 $ 160 $ 97 $ 98 (a) VP-Arica TargetCo LLC consolidates VP-Arica TE Holdco LLC, a consolidated VIE that owns the Victory Pass and Arica solar projects. (b) Other is comprised of Elbow Creek TE Holdco LLC, Pinnacle Repowering TE Holdco LLC and the Spring Canyon projects. |
Fair Value of Financial Instr_2
Fair Value of Financial Instruments (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Fair Value Disclosures [Abstract] | |
Schedule of Estimated Carrying Amounts 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, 2023 As of December 31, 2022 Carrying Amount Fair Value Carrying Amount Fair Value (In millions) Liabilities: Long-term debt, including current portion (a) $ 8,102 $ 7,611 $ 6,874 $ 6,288 (a) Excludes net debt issuance costs, which are recorded as a reduction to long-term debt on the Company’s consolidated balance sheets. |
Scchedule 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, 2023 As of December 31, 2022 Level 2 Level 3 Level 2 Level 3 (In millions) Long-term debt, including current portion $ 1,939 $ 5,672 $ 1,834 $ 4,454 |
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, 2023 As of December 31, 2022 Fair Value Fair Value (a) Fair Value Fair Value (a) (In millions) Level 2 (b) Level 3 Level 2 Level 3 Derivative assets Energy-related commodity contracts (c) $ 2 $ — $ — $ — Interest rate contracts 121 — 89 — Other financial instruments (d) — 13 — 17 Total assets $ 123 $ 13 $ 89 $ 17 Derivative liabilities Energy-related commodity contracts (e) $ — $ 330 $ — $ 353 Interest rate contracts 2 — — — Total liabilities $ 2 $ 330 $ — $ 353 (a) There were no derivative assets or liabilities classified as Level 1 as of December 31, 2023 and 2022. (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 long-term backbone transportation service contracts entered into by El Segundo and Walnut Creek during 2023. (d) Includes SREC contract. (e) Includes $325 million related to long-term power commodity contracts and $5 million related to short-term heat rate call option contracts entered into by El Segundo, Marsh Landing and Walnut Creek during 2023. 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, 2023 2022 (In millions) Fair Value Measurement Using Significant Unobservable Inputs (Level 3) Beginning balance $ (336) $ (154) Settlements 28 61 Additions due to loss of NPNS exception — (22) Total losses for the period included in earnings (9) (221) Ending balance $ (317) $ (336) Change in unrealized losses included in earnings for derivatives and other financial instruments held as of December 31, $ (9) $ (221) The following table quantifies the significant unobservable inputs used in developing the fair value of the Company’s Level 3 positions as of December 31, 2023: December 31, 2023 Fair Value Input/Range Assets Liabilities Valuation Technique Significant Unobservable Input Low High Weighted Average (In millions) Long-term Power Commodity Contracts $ — $ 325 Discounted Cash Flow Forward Market Price (per MWh) $ 18.18 $ 81.62 $ 39.91 Heat Rate Call Option Commodity Contracts — 5 Option Model Forward Market Price (per MWh) $ (43.96) $ 343.61 $ 64.34 Option Model Forward Market Price (per MMBtu) $ 1.25 $ 13.69 $ 4.93 Other Financial Instruments 13 — Discounted Cash Flow Forecast annual generation levels of certain DG solar facilities 60,801 MWh 121,602 MWh 115,622 MWh |
Schedule of Fair Value Measurement Inputs and Valuation Techniques | The following table provides the impact on the fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2023: 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) |
Accounting for Derivative Ins_2
Accounting for Derivative Instruments and Hedging Activities (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Summary of Net Notional Volume Buy/(Sell) of NRG Yield's Open Derivative Transactions Broken Out by Commodity | 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, 2023 December 31, 2022 Commodity Units (In millions) Power MWh (23) (18) Natural Gas MMBtu 17 — Interest Dollars $ 2,467 $ 1,084 |
Schedule of Fair Value Within the Derivative Instrument Valuation on the Balance Sheets | 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, 2023 December 31, 2022 December 31, 2023 December 31, 2022 (In millions) Derivatives Designated as Cash Flow Hedges: Interest rate contracts current $ 7 $ 7 $ — $ — Interest rate contracts long-term 12 18 2 — Total Derivatives Designated as Cash Flow Hedges $ 19 $ 25 $ 2 $ — Derivatives Not Designated as Cash Flow Hedges: Interest rate contracts current $ 33 $ 19 $ — $ — Interest rate contracts long-term 69 45 — — Energy-related commodity contracts current 1 — 51 50 Energy-related commodity contracts long-term 1 — 279 303 Total Derivatives Not Designated as Cash Flow Hedges $ 104 $ 64 $ 330 $ 353 Total Derivatives $ 123 $ 89 $ 332 $ 353 |
Schedule of Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid | The following tables summarize the offsetting of derivatives by counterparty: Gross Amounts Not Offset in the Statement of Financial Position As of December 31, 2023 Gross Amounts of Recognized Assets/Liabilities Derivative Instruments Net Amount Energy-related commodity contracts (In millions) Derivative assets $ 2 $ — $ 2 Derivative liabilities (330) — (330) Total energy-related commodity contracts $ (328) $ — $ (328) Interest rate contracts Derivative assets $ 121 $ (2) $ 119 Derivative liabilities (2) 2 — Total interest rate contracts $ 119 $ — $ 119 Total derivative instruments $ (209) $ — $ (209) Gross Amounts Not Offset in the Statement of Financial Position As of December 31, 2022 Gross Amounts of Recognized Assets/Liabilities Derivative Instruments Net Amount Energy-related commodity contracts (In millions) Derivative liabilities $ (353) $ — $ (353) Total energy-related commodity contracts $ (353) $ — $ (353) Interest rate contracts Derivative assets $ 89 $ — $ 89 Total interest rate contracts $ 89 $ — $ 89 Total derivative instruments $ (264) $ — $ (264) |
Summary of Effects of NRG Yield's Accumulated OCI Balance Attributable to Interest Rate Swaps Designated as Cash Flow Hedge Derivatives, Net of Tax | 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, net of tax: Year ended December 31, 2023 2022 2021 (In millions) Accumulated OCI (OCL) beginning balance $ 24 $ (11) $ (30) Reclassified from accumulated OCI (OCL) to income due to realization of previously deferred amounts (4) 4 8 Capistrano Wind Portfolio Acquisition (a) — 7 — Mark-to-market of cash flow hedge accounting contracts (2) 24 11 Accumulated OCI (OCL) ending balance, net of income tax expense (benefit) of $2, $3 and $(2), respectively 18 24 (11) Accumulated OCI (OCL) attributable to noncontrolling interests 11 15 (5) Accumulated OCI (OCL) attributable to Clearway Energy, Inc. $ 7 $ 9 $ (6) Income expected to be realized from OCI during the next 12 months, net of income tax expense of $1 $ 4 (a) Represents $4 million attributable to Clearway Energy, Inc. and $3 million attributable to noncontrolling interests. |
Schedule of Derivative Gains and Losses | Mark-to-market gains/(losses) related to the Company’s derivatives are recorded in the consolidated statements of income as follows: Year ended December 31, 2023 2022 2021 (In millions) Interest Rate Contracts (Interest expense) $ (17) $ 100 $ 53 Energy-Related Commodity Contracts (Mark-to-market for economic hedging activities included in Total operating revenues) (a) 23 (174) (83) Energy-Related Commodity Contracts (Mark-to-market for economic hedging activities included in Cost of operations) (b) 2 — — (a) Relates to long-term energy-related commodity contracts at Elbow Creek, Mesquite Star, Mt. Storm, Langford and Mesquite Sky and short-term heat rate call option energy-related commodity contracts at El Segundo, Marsh Landing and Walnut Creek. During the year ended December 31, 2022, the energy-related commodity contract for Langford, which previously met the NPNS exception, no longer qualified for NPNS treatment and, accordingly, is accounted for as a derivative and marked to fair value through operating revenues. (b) Relates to long-term backbone transportation service energy-related commodity contracts at El Segundo and Walnut Creek. |
Intangible Assets (Tables)
Intangible Assets (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Goodwill and Intangible Assets Disclosure [Abstract] | |
Summary 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, 2023 PPAs Leasehold Rights Emission Allowances Other Total (In millions) January 1, 2023 $ 3,321 $ 86 $ 17 $ 18 $ 3,442 Walnut Creek PPA expiration (50) — — — (50) Other (6) — — (3) (9) December 31, 2023 3,265 86 17 15 3,383 Less accumulated amortization (962) (38) (4) (5) (1,009) Net carrying amount $ 2,303 $ 48 $ 13 $ 10 $ 2,374 Year ended December 31, 2022 PPAs Leasehold Rights Emission Other Total (In millions) January 1, 2022 $ 2,985 $ 86 $ 17 $ 16 $ 3,104 Acquisitions (a) 336 — — — 336 Other — — — 2 2 December 31, 2022 3,321 86 17 18 3,442 Less accumulated amortization (833) (34) (4) (6) (877) Net carrying amount $ 2,488 $ 52 $ 13 $ 12 $ 2,565 (a) The weighted average life of acquired intangibles was 10 years for PPAs. |
Schedule Future Amortization Expense for Intangibles | The Company estimates the future amortization expense for its intangibles for the next five years as follows: (In millions) 2024 $ 184 2025 184 2026 184 2027 183 2028 183 |
Long-term Debt (Tables)
Long-term Debt (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Debt Disclosure [Abstract] | |
Schedule of Long-term Debt | The Company’s borrowings, including short-term and long-term portions, consisted of the following: December 31, 2023 December 31, 2022 Interest rate % (a)(b) Letters of Credit Outstanding at December 31, 2023 (In millions, except rates) 2028 Senior Notes $ 850 $ 850 4.750 2031 Senior Notes 925 925 3.750 2032 Senior Notes 350 350 3.750 Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 (b) — — S+1.850 $ 246 Non-recourse project-level debt: — Agua Caliente Solar LLC, due 2037 612 649 2.395-3.633 45 Alta Wind Asset Management LLC, due 2031 11 12 S+2.775 — Alta Wind I-V lease financing arrangements, due 2034 and 2035 660 709 5.696-7.015 67 Alta Wind Realty Investments LLC, due 2031 20 22 7.000 — Borrego, due 2024 and 2038 48 51 Various 4 Broken Bow, due 2031 41 45 S+2.100 6 Buckthorn Solar, due 2025 116 119 S+2.100 20 Carlsbad Energy Holdings LLC, due 2027 93 115 S+1.900 63 Carlsbad Energy Holdings LLC, due 2038 407 407 4.120 — Carlsbad Holdco, LLC, due 2038 195 197 4.210 5 Cedro Hill, due 2024 and 2029 165 82 S+1.375 — Crofton Bluffs, due 2031 27 29 S+2.100 3 CVSR, due 2037 601 627 2.339-3.775 — CVSR Holdco Notes, due 2037 152 160 4.680 12 Daggett 2, due 2028 156 — S+1.762 36 Daggett 3, due 2028 217 — S+1.762 43 DG-CS Master Borrower LLC, due 2040 385 413 3.510 30 Mililani I, due 2027 (c) — 47 S+1.600 — Mililani Class B Member Holdco LLC, due 2028 (c) 92 — S+1.600 18 NIMH Solar, due 2024 148 163 S+2.275 10 Oahu Solar Holdings LLC, due 2026 81 83 S+1.525 9 Rosie Class B LLC, due 2024 and 2029 347 76 S+1.250-1.375 24 Texas Solar Nova 1, due 2028 102 — S+1.750 55 Utah Solar Portfolio, due 2036 242 257 3.590 155 Viento Funding II, LLC, due 2029 175 184 S+1.475 25 Victory Pass and Arica, due 2024 757 — S+1.125 5 Waiawa, due 2028 (c) — 97 S+1.600 — Other 124 201 Various 63 Subtotal non-recourse project-level debt 5,974 4,745 Total debt 8,099 6,870 Less current maturities (558) (322) Less net debt issuance costs (65) (61) Add premiums (d) 3 4 Total long-term debt $ 7,479 $ 6,491 (a) As of December 31, 2023, S+ equals SOFR plus x%. (b) Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement. (c) On July 21, 2023, Mililani I’s financing agreement was amended to merge the project-level debt of Mililani I and Waiawa as a combined term loan under Mililani Class B Member Holdco LLC. (d) Premiums relate to the 2028 Senior Notes. |
Summary of Swaps Related to the Company's Project Level Debt | The following table summarizes the swaps, some of which are forward starting as indicated, related to the Company’s project level debt: % of Principal Fixed Interest Rate Floating Interest Rate Notional Amount at December 31, 2023 (In millions) Effective Date Maturity Date Avra Valley 85 % 2.20 % SOFR $ 29 March 31, 2023 January 31, 2031 Alta Wind Asset Management 100 % 2.22 % SOFR 11 May 22, 2013 May 15, 2031 Borrego 100 % 0.21 % SOFR 3 June 30, 2020 December 31, 2024 Broken Bow 90 % Various SOFR 37 Various Various Buckthorn Solar 80 % Various SOFR 93 February 28, 2018 December 31, 2041 Carlsbad Energy Holdings 100 % Various SOFR 93 Various September 30, 2027 Cedro Hill 86 % Various SOFR 142 December 12, 2023 Various Crofton Bluffs 90 % Various SOFR 24 Various Various Daggett 2 90 % 2.22 % SOFR 141 August 3, 2022 March 31, 2043 Daggett 3 86 % 1.91 % SOFR 186 Various September 30, 2043 Kansas South 75 % 1.93 % SOFR 12 June 28, 2013 December 31, 2030 Mililani Class B 98 % Various SOFR 90 Various Various NIMH Solar 100 % Various SOFR 148 September 30, 2020 Various Oahu Solar 96 % 2.47 % SOFR 77 November 30, 2019 October 31, 2040 Rosie Class B 53 % Various SOFR 182 Various Various South Trent 90 % Various SOFR 22 June 14, 2019 June 30, 2028 Texas Solar Nova 1 94 % 2.92 % SOFR 97 October 31, 2022 June 30, 2043 Viento Funding II 90 % 2.53 % SOFR 158 Various December 31, 2032 Victory Pass and Arica 122 % 4.18 % SOFR 922 November 30, 2022 January 31, 2024 Total $ 2,467 |
Schedule of Annual Payments Based on the Maturities of NRG Yield's Debt | Annual payments based on the maturities of the Company’s debt, for the years ending after December 31, 2023, are as follows: (In millions) 2024 (a) $ 1,669 2025 371 2026 351 2027 288 2028 1,662 Thereafter 3,758 Total $ 8,099 (a) At December 31, 2023, amount includes $1.11 billion of construction-related financings recorded in long-term debt on the Company’s consolidated balance sheet that is due in 2024 and is either being funded through long-term equity contributions or is converting to long-term debt. |
Earnings Per Share (Tables)
Earnings Per Share (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Earnings Per Share [Abstract] | |
Schedule of Earnings Per Share, Basic | The reconciliation of the Company’s basic and diluted earnings per share is shown in the following table: Year Ended December 31, 2023 2022 2021 (In millions, except per share data) (a) Common Class A Common Class C Common Class A Common Class C Common Class A Common Class C Basic and diluted income per share attributable to Clearway Energy, Inc. common stockholders Net income attributable to Clearway Energy, Inc. $ 23 $ 56 $ 172 $ 410 $ 15 $ 36 Weighted average number of common shares outstanding — basic and diluted 35 82 35 82 35 82 Earnings per weighted average common share — basic and diluted $ 0.67 $ 0.67 $ 4.99 $ 4.99 $ 0.44 $ 0.44 (a) |
Schedule of Earnings Per Share, Diluted | The reconciliation of the Company’s basic and diluted earnings per share is shown in the following table: Year Ended December 31, 2023 2022 2021 (In millions, except per share data) (a) Common Class A Common Class C Common Class A Common Class C Common Class A Common Class C Basic and diluted income per share attributable to Clearway Energy, Inc. common stockholders Net income attributable to Clearway Energy, Inc. $ 23 $ 56 $ 172 $ 410 $ 15 $ 36 Weighted average number of common shares outstanding — basic and diluted 35 82 35 82 35 82 Earnings per weighted average common share — basic and diluted $ 0.67 $ 0.67 $ 4.99 $ 4.99 $ 0.44 $ 0.44 (a) |
Stockholders' Equity (Tables)
Stockholders' Equity (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Equity, Attributable to Parent [Abstract] | |
Schedule of Dividends Paid | The following table lists the dividends paid on the Company’s Class A and Class C common stock during the year ended December 31, 2023: Fourth Quarter 2023 Third Quarter 2023 Second Quarter 2023 First Quarter 2023 Dividends per Class A share $ 0.3964 $ 0.3891 $ 0.3818 $ 0.3745 Dividends per Class C share 0.3964 0.3891 0.3818 0.3745 |
Schedule of Distributions Paid | The following table lists the distributions paid to CEG during the year ended December 31, 2023 on Clearway Energy LLC’s Class B and D units: Fourth Quarter 2023 Third Quarter 2023 Second Quarter 2023 First Quarter 2023 Distributions per Class B unit $ 0.3964 $ 0.3891 $ 0.3818 $ 0.3745 Distributions per Class D unit 0.3964 0.3891 0.3818 0.3745 |
Segment Reporting (Tables)
Segment Reporting (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
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, 2023, 2022 and 2021: 2023 2022 2021 Customer Conventional Renewables Conventional Renewables Conventional Renewables SCE 11% 13% 17% 17% 17% 16% PG&E 4% 13% 10% 15% 10% 13% |
Schedule of Segment Reporting Information | Year ended December 31, 2023 (In millions) Conventional Generation Renewables 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 — — 36 36 Transaction and integration costs — — 4 4 Operating income (loss) 137 164 (38) 263 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) (111) (16) Income tax (benefit) expense — (2) — (2) Net Income (Loss) 109 (12) (111) (14) Net Income (Loss) Attributable to Clearway Energy, Inc. $ 109 $ 150 $ (180) $ 79 Balance Sheet Equity investments in affiliates $ 79 $ 281 $ — $ 360 Capital expenditures (b) 11 146 — 157 Total Assets $ 2,058 $ 12,205 $ 438 $ 14,701 (a) Includes eliminations. (b) Includes accruals. Year ended December 31, 2022 (In millions) Conventional Generation Renewables Thermal Corporate (a) Total Operating revenues $ 417 $ 696 $ 77 $ — $ 1,190 Cost of operations, exclusive of depreciation, amortization and accretion shown separately below 89 298 50 (2) 435 Depreciation, amortization and accretion 131 381 — — 512 Impairment losses — 16 — — 16 General and administrative — — 2 38 40 Transaction and integration costs — — — 7 7 Development costs — — 2 — 2 Total operating costs and expenses 220 695 54 43 1,012 Gain on sale of business — — — 1,292 1,292 Operating income 197 1 23 1,249 1,470 Equity in earnings of unconsolidated affiliates 3 26 — — 29 Other income, net 1 6 — 10 17 Loss on debt extinguishment — (2) — — (2) Interest expense (40) (87) (6) (99) (232) Income (loss) before income taxes 161 (56) 17 1,160 1,282 Income tax expense — 2 — 220 222 Net Income (Loss) 161 (58) 17 940 1,060 Net Income Attributable to Clearway Energy, Inc. $ 161 $ 49 $ 17 $ 355 $ 582 Balance Sheet Equity investments in affiliates $ 82 $ 282 $ — $ — $ 364 Capital expenditures (b)(c) 11 33 11 1 56 Total Assets $ 2,251 $ 9,515 $ — $ 546 $ 12,312 (a) Includes eliminations. (b) Includes accruals. (c) Thermal capital expenditures, including accruals, prior to the sale of the Thermal Business on May 1, 2022. Year ended December 31, 2021 (In millions) Conventional Generation Renewables Thermal Corporate (a) Total Operating revenues $ 441 $ 641 $ 204 $ — $ 1,286 Cost of operations, exclusive of depreciation, amortization and accretion shown separately below 90 229 134 (2) 451 Depreciation, amortization and accretion 132 354 23 — 509 Impairment losses — 6 — — 6 General and administrative — — 4 36 40 Transaction and integration costs — — — 7 7 Development costs — — 4 2 6 Operating income (loss) 219 52 39 (43) 267 Equity in earnings of unconsolidated affiliates 6 26 — — 32 Other income, net — 2 1 — 3 Loss on debt extinguishment — (1) — (52) (53) Interest expense (53) (142) (18) (99) (312) Income (loss) before income taxes 172 (63) 22 (194) (63) Income tax expense — 2 — 10 12 Net Income (Loss) 172 (65) 22 (204) (75) Net Income (Loss) Attributable to Clearway Energy, Inc. $ 172 $ 109 $ 22 $ (252) $ 51 (a) Includes eliminations. |
Income Taxes (Tables)
Income Taxes (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Income Tax Disclosure [Abstract] | |
Schedule of Income Tax Provision From Continuing Operations | The income tax provision consisted of the following amounts: Year Ended December 31, 2023 2022 2021 (In millions) Current U.S. Federal $ (13) $ — $ — State (2) 28 — Total — current (15) 28 — Deferred U.S. Federal $ 13 $ 150 $ (2) State — 44 14 Total — deferred 13 194 12 Total income tax (benefit) expense $ (2) $ 222 $ 12 |
Schedule of Reconciliation of the U.S. Federal Statutory Rate to the Company's Effective Rate | A reconciliation of the U.S. federal statutory rate of 21% to the Company’s effective rate is as follows: Year Ended December 31, 2023 2022 2021 (In millions, except percentages) (Loss) Income Before Income Taxes $ (16) $ 1,282 $ (63) Tax at 21% (3) 269 (13) State taxes, net of federal benefit (2) 58 (4) Impact of non-taxable partnership earnings (losses) 21 (101) 34 Valuation allowance 3 — (14) Investment tax credits (1) — — Production tax credits (a) (16) (2) (1) Rate change 1 (2) (2) Partnership state basis — — 8 State taxes assessed at subsidiaries (3) 2 2 Other (2) (2) 2 Income tax (benefit) expense $ (2) $ 222 $ 12 Effective income tax rate 12.5 % 17.3 % (19.0) % (a) On December 6, 2023, the Company executed an agreement with a third party to sell the PTCs generated by the Alta X and Alta XI wind projects, which resulted in a $14 million income tax benefit (reduction to income tax expense) during the year ended December 31, 2023. |
Schedule of Company's Deferred Tax Assets and Liabilities | The temporary differences, which gave rise to the Company’s deferred tax balances consisted of the following: As of December 31, 2023 2022 (In millions) Deferred tax liabilities: Investment in projects $ 241 $ 240 Total deferred tax liabilities 241 240 Deferred tax assets: Interest expense disallowance carryforward - Investment in Projects $ 17 $ — Production tax credits 15 13 Investment tax credits 6 5 U.S. Federal net operating loss carryforwards 73 100 State net operating loss carryforwards 7 4 Total deferred tax assets 118 122 Valuation allowance (4) (1) Total deferred tax assets, net of valuation allowance 114 121 Net deferred non-current tax liability $ (127) $ (119) |
Leases (Tables)
Leases (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Leases [Abstract] | |
Schedule of Lease Information and Expense | Lease expense was comprised of the following: Year Ended December 31, (In millions) 2023 2022 2021 Operating lease cost - Fixed $ 40 $ 36 $ 27 Operating lease cost - Variable 11 11 15 Total lease cost $ 51 $ 47 $ 42 Operating lease information was as follows: (In millions, except term and rate) December 31, 2023 December 31, 2022 Right-of-use assets - operating leases, net (a) $ 597 $ 527 Short-term lease liability - operating leases (b) $ 7 $ 6 Long-term lease liability - operating leases (a) 627 548 Total lease liabilities $ 634 $ 554 Weighted average remaining lease term (in years) 28 27 Weighted average discount rate 4.2 % 4.1 % Cash paid for operating leases $ 30 $ 28 (a) Increases in right-of-use assets and long-term lease liabilities are primarily due to Drop Down Asset 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, 2023 and 2022. |
Schedule of Maturities of Operating Lease Liabilities | Minimum future rental payments of operating lease liabilities as of December 31, 2023 are as follows: (In millions) 2024 $ 34 2025 34 2026 35 2027 36 2028 36 Thereafter 980 Total lease payments 1,155 Less imputed interest (521) Total lease liability - operating leases $ 634 |
Schedule of Components of Leveraged Lease Investments | 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, 2023 Daggett 2 $ 22 $ 23 June 30, 2058 Daggett 3 31 33 December 18, 2062 Mililani I 19 20 March 31, 2057 Oahu Solar (a) 17 20 August 1, 2057 Rosamond Central (a) 11 12 March 31, 2056 As of December 31, 2022 Mililani I $ 19 $ 20 Oahu Solar (a) 17 20 Rosamond Central (a) 11 12 (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 revenue are related to the Company’s operating leases: Conventional Generation Renewables Total December 31, 2023 (In millions) Energy revenue $ 4 $ 760 $ 764 Capacity revenue 249 20 269 Other revenue (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 will receive 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. Conventional Generation Renewables Thermal Total December 31, 2022 (In millions) Energy revenue $ 6 $ 809 $ 1 $ 816 Capacity revenue 435 — — 435 Operating revenues $ 441 $ 809 $ 1 $ 1,251 Conventional Generation Renewables Thermal Total December 31, 2021 (In millions) Energy revenue $ 9 $ 716 $ 2 $ 727 Capacity revenue 455 — — 455 Operating revenues $ 464 $ 716 $ 2 $ 1,182 |
Schedule of Minimum Future Rent Payments Under the Operating Leases | Minimum future rent payments for the remaining periods related to the Company’s operating leases as of December 31, 2023 were as follows: (In millions) 2024 $ 146 2025 147 2026 148 2027 149 2028 150 Thereafter 1,635 Total lease payments $ 2,375 |
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, 2023 December 31, 2022 Property, plant and equipment $ 5,720 $ 8,630 Accumulated depreciation (1,991) (2,855) Net property, plant and equipment $ 3,729 $ 5,775 |
Nature of Business (Details)
Nature of Business (Details) | 12 Months Ended |
Dec. 31, 2023 MW | |
Collaborative Arrangement and Arrangement Other than Collaborative [Line Items] | |
Power generation capacity, megawatts (over) | 8,500 |
Clearway Energy, Inc. | Clearway Energy LLC | |
Collaborative Arrangement and Arrangement Other than Collaborative [Line Items] | |
Ownership interest (as a percentage) | 57.90% |
Clearway Energy, Inc. | CEG | |
Collaborative Arrangement and Arrangement Other than Collaborative [Line Items] | |
Voting Interest (as a percentage) | 45.07% |
Clearway Energy, Inc. | Public Shareholders | |
Collaborative Arrangement and Arrangement Other than Collaborative [Line Items] | |
Voting Interest (as a percentage) | 54.93% |
Clearway Energy LLC | CEG | |
Collaborative Arrangement and Arrangement Other than Collaborative [Line Items] | |
Ownership interest (as a percentage) | 42.10% |
Conventional Generation, Utility-Scale Solar, Distributed Solar, and Wind | |
Collaborative Arrangement and Arrangement Other than Collaborative [Line Items] | |
Power generation capacity, megawatts (over) | 6,000 |
Generational Facilities and District Energy Systems | |
Collaborative Arrangement and Arrangement Other than Collaborative [Line Items] | |
Power generation capacity, megawatts (over) | 2,500 |
Summary of Significant Accoun_4
Summary of Significant Accounting Policies - Narrative (Details) - USD ($) | 12 Months Ended | |||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | May 01, 2022 | |
Summary of Significant Accounting Policies [Line Items] | ||||
Restricted cash | $ 176,000,000 | |||
Restricted cash, current | 516,000,000 | $ 339,000,000 | ||
Allowance for credit losses | 0 | 0 | ||
Interest costs capitalized | 36,000,000 | 2,000,000 | $ 3,000,000 | |
Contingent lease revenue recognized | $ 780,000,000 | $ 850,000,000 | $ 741,000,000 | |
Income tax benefit threshold | 50% | |||
Operating Lease, Lease Income, Statement of Income or Comprehensive Income [Extensible Enumeration] | Operating revenues | Operating revenues | Operating revenues | |
Disposed of by Sale | Thermal | ||||
Summary of Significant Accounting Policies [Line Items] | ||||
Assets ownership sold (as a percentage) | 100% | |||
Long-Term Debt, Current | ||||
Summary of Significant Accounting Policies [Line Items] | ||||
Restricted cash, current | $ 178,000,000 | |||
Debt Service Obligations | ||||
Summary of Significant Accounting Policies [Line Items] | ||||
Restricted cash, current | 85,000,000 | |||
Cash Distribution | ||||
Summary of Significant Accounting Policies [Line Items] | ||||
Restricted cash, current | 77,000,000 | |||
Operating Funds | ||||
Summary of Significant Accounting Policies [Line Items] | ||||
Restricted cash, current | 176,000,000 | |||
Project Level Subsidiaries | ||||
Summary of Significant Accounting Policies [Line Items] | ||||
Cash and cash equivalents held at project subsidiaries | $ 125,000,000 | $ 121,000,000 |
Summary of Significant Accoun_5
Summary of Significant Accounting Policies - Cash and Cash Equivalents, and Restricted Cash (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 |
Accounting Policies [Abstract] | ||||
Cash and cash equivalents | $ 535 | $ 657 | ||
Restricted cash | 516 | 339 | ||
Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows | $ 1,051 | $ 996 | $ 654 | $ 465 |
Summary of Significant Accoun_6
Summary of Significant Accounting Policies - Supplemental Cash Flow Information (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Summary of Significant Accounting Policies [Line Items] | |||
Acquisition of Drop Down Assets, net of cash acquired | $ (45) | $ (71) | $ (229) |
Drop Down | |||
Summary of Significant Accounting Policies [Line Items] | |||
Cash paid to acquire Drop Down Assets | (173) | (71) | (230) |
Cash acquired from the acquisition of Drop Down Assets | 128 | 0 | 1 |
Acquisition of Drop Down Assets, net of cash acquired | $ (45) | $ (71) | $ (229) |
Summary of Significant Accoun_7
Summary of Significant Accounting Policies - Disaggregated Revenues (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Disaggregation of Revenue [Line Items] | |||
Operating revenues | $ 1,314 | $ 1,190 | $ 1,286 |
Mark-to-market for economic hedges | 19 | ||
Total operating revenues | 1,314 | $ 1,190 | $ 1,286 |
Less: Mark-to-market for economic hedges | $ (19) | ||
Operating Lease, Lease Income, Statement of Income or Comprehensive Income [Extensible Enumeration] | Total operating revenues | Total operating revenues | Total operating revenues |
Conventional Generation | Energy revenue | |||
Disaggregation of Revenue [Line Items] | |||
Less: Lease revenue | $ 4 | $ 6 | $ 9 |
Conventional Generation | Capacity revenue | |||
Disaggregation of Revenue [Line Items] | |||
Less: Lease revenue | 249 | 435 | 455 |
Renewables | Energy revenue | |||
Disaggregation of Revenue [Line Items] | |||
Less: Lease revenue | 760 | 809 | 716 |
Renewables | Capacity revenue | |||
Disaggregation of Revenue [Line Items] | |||
Less: Lease revenue | 20 | 0 | 0 |
Thermal | Energy revenue | |||
Disaggregation of Revenue [Line Items] | |||
Less: Lease revenue | 1 | 2 | |
Thermal | Capacity revenue | |||
Disaggregation of Revenue [Line Items] | |||
Less: Lease revenue | 0 | 0 | |
Operating Segments | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 1,314 | 1,190 | 1,286 |
Contract amortization | (186) | (175) | (144) |
Mark-to-market for economic hedges | 19 | (182) | (87) |
Total operating revenues | 1,314 | 1,190 | 1,286 |
Less: Contract amortization | 186 | 175 | 144 |
Less: Mark-to-market for economic hedges | (19) | 182 | 87 |
Less: Lease revenue | 1,054 | 1,251 | 1,182 |
Total revenue from contracts with customers | 427 | 296 | 335 |
Operating Segments | Energy revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 1,023 | 1,010 | 915 |
Total operating revenues | 1,023 | 1,010 | 915 |
Operating Segments | Capacity revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 359 | 455 | 510 |
Total operating revenues | 359 | 455 | 510 |
Operating Segments | Other revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 99 | 82 | 92 |
Total operating revenues | 99 | 82 | 92 |
Operating Segments | Conventional Generation | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 420 | 417 | 441 |
Contract amortization | (20) | (24) | (23) |
Mark-to-market for economic hedges | (5) | 0 | 0 |
Total operating revenues | 420 | 417 | 441 |
Less: Contract amortization | 20 | 24 | 23 |
Less: Mark-to-market for economic hedges | 5 | 0 | 0 |
Less: Lease revenue | 274 | 441 | 464 |
Total revenue from contracts with customers | 171 | 0 | 0 |
Operating Segments | Conventional Generation | Energy revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 81 | 6 | 9 |
Total operating revenues | 81 | 6 | 9 |
Operating Segments | Conventional Generation | Capacity revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 336 | 435 | 455 |
Total operating revenues | 336 | 435 | 455 |
Operating Segments | Conventional Generation | Other revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 28 | 0 | 0 |
Total operating revenues | 28 | 0 | 0 |
Operating Segments | Renewables | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 894 | 696 | 641 |
Contract amortization | (166) | (151) | (118) |
Mark-to-market for economic hedges | 24 | (182) | (87) |
Total operating revenues | 894 | 696 | 641 |
Less: Contract amortization | 166 | 151 | 118 |
Less: Mark-to-market for economic hedges | (24) | 182 | 87 |
Less: Lease revenue | 780 | 809 | 716 |
Total revenue from contracts with customers | 256 | 220 | 130 |
Operating Segments | Renewables | Energy revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 942 | 956 | 784 |
Total operating revenues | 942 | 956 | 784 |
Operating Segments | Renewables | Capacity revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 23 | 2 | 2 |
Total operating revenues | 23 | 2 | 2 |
Operating Segments | Renewables | Other revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 71 | 71 | 60 |
Total operating revenues | $ 71 | 71 | 60 |
Operating Segments | Thermal | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 77 | 204 | |
Contract amortization | 0 | (3) | |
Mark-to-market for economic hedges | 0 | 0 | |
Total operating revenues | 77 | 204 | |
Less: Contract amortization | 0 | 3 | |
Less: Mark-to-market for economic hedges | 0 | 0 | |
Less: Lease revenue | 1 | 2 | |
Total revenue from contracts with customers | 76 | 205 | |
Operating Segments | Thermal | Energy revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 48 | 122 | |
Total operating revenues | 48 | 122 | |
Operating Segments | Thermal | Capacity revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 18 | 53 | |
Total operating revenues | 18 | 53 | |
Operating Segments | Thermal | Other revenue | |||
Disaggregation of Revenue [Line Items] | |||
Operating revenues | 11 | 32 | |
Total operating revenues | $ 11 | $ 32 |
Summary of Significant Accoun_8
Summary of Significant Accounting Policies - Contract Balances (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||
Total accounts receivable, net | $ 171 | $ 153 |
Customer Contracts | ||
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||
Total accounts receivable, net | 66 | 37 |
Lease Agreements | ||
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||
Total accounts receivable, net | $ 105 | $ 116 |
Summary of Significant Accoun_9
Summary of Significant Accounting Policies - Asset Retirement Obligation (Details) $ in Millions | 12 Months Ended |
Dec. 31, 2023 USD ($) | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |
Balance as of December 31, 2022 | $ 157 |
Revisions in estimated cash flows | 3 |
Liabilities incurred | 67 |
Accretion expense | 12 |
Balance as of December 31, 2023 | $ 239 |
Summary of Significant Accou_10
Summary of Significant Accounting Policies -Redeemable Noncontrolling Interests (Details) - USD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2023 | Dec. 31, 2022 | |
Increase (Decrease) in Temporary Equity [Roll Forward] | ||
Balance at December 31, 2022 | $ 7 | $ 0 |
Cash distributions to redeemable noncontrolling interests | (3) | (4) |
Comprehensive income attributable to redeemable noncontrolling interests | 17 | 11 |
Repurchase of redeemable noncontrolling interest | (20) | |
Balances at December 31, 2023 | $ 1 | $ 7 |
Acquisitions and Dispositions -
Acquisitions and Dispositions - Acquisitions Narrative (Details) $ in Millions | Dec. 28, 2023 USD ($) MW | Dec. 01, 2023 USD ($) MW | Oct. 31, 2023 USD ($) MW | Aug. 30, 2023 USD ($) MW | Feb. 17, 2023 USD ($) MW | Oct. 03, 2022 USD ($) MW | Aug. 22, 2022 USD ($) project MW | Mar. 25, 2022 USD ($) MW | Dec. 31, 2023 MW |
Business Acquisition [Line Items] | |||||||||
Power generation capacity, megawatts (over) | MW | 8,500 | ||||||||
Texas Solar Nova 1 Drop Down | |||||||||
Business Acquisition [Line Items] | |||||||||
Net liabilities assumed | $ (6) | ||||||||
Texas Solar Nova 1 Drop Down | CEG | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments to fund project reserve accounts | $ 23 | ||||||||
Rosamond Central Solar Project | |||||||||
Business Acquisition [Line Items] | |||||||||
Net liabilities assumed | $ 266 | ||||||||
Rosamond Central Solar Project | Rosie Central BESS | |||||||||
Business Acquisition [Line Items] | |||||||||
Power generation capacity, megawatts (over) | MW | 147 | ||||||||
Payments for asset acquisition | $ 70 | ||||||||
Power purchase agreement period (in years) | 15 years | ||||||||
Current assets, receivables | $ 279 | ||||||||
Rosamond Central Solar Project | Rosie Central BESS | Clearway Renew LLC | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments for asset acquisition | 16 | ||||||||
Current assets, receivables | 61 | ||||||||
Rosamond Central Solar Project | Tax Equity Investors | Rosie Central BESS | |||||||||
Business Acquisition [Line Items] | |||||||||
Current assets, receivables | 218 | ||||||||
Rosamond Central Solar Project | Cash Equity Investor | Rosie Central BESS | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments for asset acquisition | $ 54 | ||||||||
Victory Pass and Arica Drop Down | |||||||||
Business Acquisition [Line Items] | |||||||||
Power generation capacity, megawatts (over) | MW | 200 | ||||||||
Power purchase agreement period (in years) | 15 years | ||||||||
Net liabilities assumed | $ (1) | ||||||||
Power generation storage capacity, megawatts | MW | 50 | ||||||||
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 | $ 182 | ||||||||
Victory Pass and Arica Drop Down | Cash Equity Investor | Clearway Renew LLC | |||||||||
Business Acquisition [Line Items] | |||||||||
Additional payments for asset acquisition | 347 | ||||||||
Daggett 2 Drop Down | |||||||||
Business Acquisition [Line Items] | |||||||||
Net liabilities assumed | $ (29) | ||||||||
Daggett 3 Drop Down | |||||||||
Business Acquisition [Line Items] | |||||||||
Net liabilities assumed | $ 15 | ||||||||
Waiawa Drop Down | |||||||||
Business Acquisition [Line Items] | |||||||||
Net liabilities assumed | $ (1) | ||||||||
Asset acquisition consideration | 20 | ||||||||
Waiawa Drop Down | Tax Equity Investors | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments to fund project reserve accounts | $ 16 | ||||||||
Capistrano Wind Portfolio Drop Down | |||||||||
Business Acquisition [Line Items] | |||||||||
Power generation capacity, megawatts (over) | MW | 413 | ||||||||
Net liabilities assumed | $ 250 | ||||||||
Asset acquisition consideration | 255 | ||||||||
Asset acquisition, purchase price adjustments, amount | 16 | ||||||||
Payments for asset acquisition, net of purchase price adjustments | $ 239 | ||||||||
Weighted average remaining contract duration | 8 years | ||||||||
Capistrano Wind Portfolio Drop Down | CEG | Non-controlling Interest | |||||||||
Business Acquisition [Line Items] | |||||||||
Net liabilities assumed | $ 4 | ||||||||
Capistrano Wind Portfolio Drop Down | Clearway Energy LLC | |||||||||
Business Acquisition [Line Items] | |||||||||
Development fees | $ 10 | ||||||||
Mililani I Drop Down | |||||||||
Business Acquisition [Line Items] | |||||||||
Net liabilities assumed | $ (8) | ||||||||
Asset acquisition consideration | 22 | ||||||||
Mililani I Drop Down | CEG | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments to fund project reserve accounts | 15 | ||||||||
Mililani I Drop Down | Tax Equity Investors | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments to fund project reserve accounts | $ 15 | ||||||||
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 | ||||||||
Alternative Energy | Lighthouse Renewable Holdco 2 LLC | Texas Solar Nova 1 Drop Down | Lighthouse Renewable Holdco 2 LLC | |||||||||
Business Acquisition [Line Items] | |||||||||
Power generation capacity, megawatts (over) | MW | 252 | ||||||||
Payments for asset acquisition | $ 23 | ||||||||
Power purchase agreement period (in years) | 18 years | ||||||||
Alternative Energy | Lighthouse Renewable Holdco 2 LLC | Texas Solar Nova 1 Drop Down | Lighthouse Renewable Holdco 2 LLC | Third Party Investor | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments for asset acquisition | $ 109 | ||||||||
Alternative Energy | Daggett TargetCo LLC | Daggett 2 Drop Down | Daggett TargetCo LLC | |||||||||
Business Acquisition [Line Items] | |||||||||
Power generation capacity, megawatts (over) | MW | 182 | ||||||||
Payments for asset acquisition | $ 13 | ||||||||
Power purchase agreement period (in years) | 15 years | ||||||||
Power generation storage capacity, megawatts | MW | 131 | ||||||||
Alternative Energy | Daggett TargetCo LLC | Daggett 3 Drop Down | Daggett TargetCo LLC | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments for asset acquisition | $ 21 | ||||||||
Power purchase agreement period (in years) | 15 years | ||||||||
Alternative Energy | Daggett TargetCo LLC | Daggett 3 Drop Down | Daggett TargetCo LLC | Cash Equity Investor | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments for asset acquisition | $ 129 | ||||||||
Alternative Energy | Lighthouse Renewable Holdco LLC | Daggett 3 Drop Down | Lighthouse Renewable Holdco LLC | |||||||||
Business Acquisition [Line Items] | |||||||||
Power generation capacity, megawatts (over) | MW | 300 | ||||||||
Power generation storage capacity, megawatts | MW | 149 | ||||||||
Alternative Energy | Lighthouse Renewable Holdco LLC | Waiawa Drop Down | Lighthouse Renewable Holdco LLC | |||||||||
Business Acquisition [Line Items] | |||||||||
Power generation capacity, megawatts (over) | MW | 36 | ||||||||
Payments for asset acquisition | $ 20 | ||||||||
Power purchase agreement period (in years) | 20 years | ||||||||
Power generation storage capacity, megawatts | MW | 36 | ||||||||
Alternative Energy | Lighthouse Renewable Holdco LLC | Waiawa Drop Down | Lighthouse Renewable Holdco LLC | Cash Equity Investor | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments for asset acquisition | $ 12 | ||||||||
Alternative Energy | Lighthouse Renewable Holdco LLC | Mililani I Drop Down | Lighthouse Renewable Holdco LLC | |||||||||
Business Acquisition [Line Items] | |||||||||
Power generation capacity, megawatts (over) | MW | 39 | ||||||||
Payments for asset acquisition | $ 22 | ||||||||
Power purchase agreement period (in years) | 20 years | ||||||||
Power generation storage capacity, megawatts | MW | 39 | ||||||||
Alternative Energy | Lighthouse Renewable Holdco LLC | Mililani I Drop Down | Lighthouse Renewable Holdco LLC | Cash Equity Investor | |||||||||
Business Acquisition [Line Items] | |||||||||
Payments for asset acquisition | $ 14 | ||||||||
Wind Power Generation and Storage | Capistrano Wind Portfolio Drop Down | Clearway Energy LLC | |||||||||
Business Acquisition [Line Items] | |||||||||
Number of projects acquired | project | 5 |
Acquisitions and Dispositions_2
Acquisitions and Dispositions - Summary of Assets and Liabilities Transferred (Details) - USD ($) $ in Millions | 12 Months Ended | |||||||||||
Dec. 28, 2023 | Dec. 22, 2023 | Dec. 01, 2023 | Oct. 31, 2023 | Aug. 30, 2023 | Jun. 30, 2023 | Feb. 17, 2023 | Dec. 07, 2022 | Oct. 03, 2022 | Aug. 22, 2022 | Mar. 25, 2022 | Dec. 31, 2023 | |
Business Acquisition [Line Items] | ||||||||||||
Removed related noncontrolling interest balance | $ 10 | |||||||||||
Texas Solar Nova 1 Drop Down | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Cash | $ 3 | |||||||||||
Property, plant and equipment, net | 362 | |||||||||||
Right-of-use assets, net | 21 | |||||||||||
Derivative assets | 4 | |||||||||||
Other non-current assets | 6 | |||||||||||
Total assets acquired | 396 | |||||||||||
Long-term debt | 349 | |||||||||||
Long-term lease liabilities | 19 | |||||||||||
Other current and non-current liabilities | 34 | |||||||||||
Total liabilities assumed | 402 | |||||||||||
Net assets (liabilities) assumed | (6) | |||||||||||
Unamortized debt issuance costs | 1 | |||||||||||
Texas Solar Nova 1 Drop Down | Construction Loans | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | 90 | |||||||||||
Texas Solar Nova 1 Drop Down | Sponsor Equity Bridge Loan | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | 109 | |||||||||||
Texas Solar Nova 1 Drop Down | Tax Equity Bridge Loan | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | $ 151 | |||||||||||
Rosamond Central Solar Project | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Property, plant and equipment, net | $ 275 | |||||||||||
Total assets acquired | 275 | |||||||||||
Other current and non-current liabilities | 9 | |||||||||||
Total liabilities assumed | 9 | |||||||||||
Net assets (liabilities) assumed | 266 | |||||||||||
Construction in progress | 272 | |||||||||||
Rosamond Central Solar Project | Construction Loans | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | $ 115 | 115 | ||||||||||
Rosamond Central Solar Project | Tax Equity Bridge Loan | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | $ 188 | $ 155 | ||||||||||
Victory Pass and Arica Drop Down | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Cash | $ 1 | |||||||||||
Property, plant and equipment, net | 937 | |||||||||||
Right-of-use assets, net | 4 | |||||||||||
Derivative assets | 1 | |||||||||||
Other 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 assets (liabilities) assumed | (1) | |||||||||||
Unamortized debt issuance costs | 4 | |||||||||||
Construction in progress | 893 | |||||||||||
Victory Pass and Arica Drop Down | Sponsor 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 | |||||||||||
Daggett 2 Drop Down | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Cash | $ 1 | |||||||||||
Restricted cash | 119 | |||||||||||
Property, plant and equipment, net | 379 | |||||||||||
Right-of-use assets, net | 22 | |||||||||||
Derivative assets | 22 | |||||||||||
Total assets acquired | 543 | |||||||||||
Long-term debt | 308 | |||||||||||
Long-term lease liabilities | 23 | |||||||||||
Other current and non-current liabilities | 28 | |||||||||||
Total liabilities assumed | 359 | |||||||||||
Noncontrolling interests | 213 | |||||||||||
Net assets (liabilities) assumed | (29) | |||||||||||
Unamortized debt issuance costs | 3 | |||||||||||
Payments for other fees | $ 1 | |||||||||||
Daggett 2 Drop Down | Construction Loans | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | 36 | 107 | ||||||||||
Daggett 2 Drop Down | Tax Equity Bridge Loan | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | $ 204 | $ 204 | ||||||||||
Daggett 3 Drop Down | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Restricted cash | $ 4 | |||||||||||
Property, plant and equipment, net | 534 | |||||||||||
Right-of-use assets, net | 31 | |||||||||||
Derivative assets | 27 | |||||||||||
Total assets acquired | 596 | |||||||||||
Long-term debt | 480 | |||||||||||
Long-term lease liabilities | 33 | |||||||||||
Other current and non-current liabilities | 68 | |||||||||||
Total liabilities assumed | 581 | |||||||||||
Net assets (liabilities) assumed | 15 | |||||||||||
Unamortized debt issuance costs | 5 | |||||||||||
Payments for other fees | 7 | |||||||||||
Daggett 3 Drop Down | CEG | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term lease liabilities | 32 | |||||||||||
Removed related noncontrolling interest balance | 22 | |||||||||||
Payments for other fees | 54 | |||||||||||
Daggett 3 Drop Down | Construction Loans | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | 40 | 181 | ||||||||||
Daggett 3 Drop Down | Sponsor Equity Bridge Loan | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | 75 | |||||||||||
Daggett 3 Drop Down | Tax Equity Bridge Loan | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | $ 229 | $ 229 | ||||||||||
Waiawa Drop Down | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Property, plant and equipment, net | $ 118 | |||||||||||
Other current and non-current assets | 7 | |||||||||||
Total assets acquired | 125 | |||||||||||
Long-term debt | 102 | |||||||||||
Other current and non-current liabilities | 24 | |||||||||||
Total liabilities assumed | 126 | |||||||||||
Net assets (liabilities) assumed | (1) | |||||||||||
Unamortized debt issuance costs | 1 | |||||||||||
Waiawa Drop Down | Construction Loans | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | 22 | |||||||||||
Waiawa Drop Down | Sponsor Equity Bridge Loan | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | 26 | |||||||||||
Waiawa Drop Down | Tax Equity Bridge Loan | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | $ 55 | |||||||||||
Capistrano Wind Portfolio Drop Down | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Restricted cash | $ 4 | |||||||||||
Property, plant and equipment, net | 147 | |||||||||||
Intangible assets for power purchase agreements | 237 | |||||||||||
Right-of-use assets, net | 27 | |||||||||||
Other current and non-current assets | 39 | |||||||||||
Total assets acquired | 450 | |||||||||||
Long-term debt | 162 | |||||||||||
Long-term lease liabilities | 28 | |||||||||||
Other current and non-current liabilities | 10 | |||||||||||
Total liabilities assumed | 200 | |||||||||||
Net assets (liabilities) assumed | 250 | |||||||||||
Cash and cash equivalents | $ 12 | |||||||||||
Mililani I Drop Down | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Property, plant and equipment, net | $ 118 | |||||||||||
Right-of-use assets, net | 19 | |||||||||||
Other current and non-current assets | 2 | |||||||||||
Total assets acquired | 139 | |||||||||||
Long-term debt | 100 | |||||||||||
Long-term lease liabilities | 20 | |||||||||||
Other current and non-current liabilities | 27 | |||||||||||
Total liabilities assumed | 147 | |||||||||||
Net assets (liabilities) assumed | (8) | |||||||||||
Unamortized debt issuance costs | 3 | |||||||||||
Payments for other fees | $ 4 | |||||||||||
Mililani I Drop Down | CEG | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Removed related noncontrolling interest balance | 11 | |||||||||||
Mililani I Drop Down | Construction Loans | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | 16 | |||||||||||
Mililani I Drop Down | Sponsor Equity Bridge Loan | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | 27 | |||||||||||
Mililani I Drop Down | Tax Equity Bridge Loan | ||||||||||||
Business Acquisition [Line Items] | ||||||||||||
Long-term debt | $ 60 | $ 60 |
Acquisitions and Dispositions_3
Acquisitions and Dispositions - Dispositions Narrative (Details) - USD ($) $ in Millions | Aug. 01, 2022 | May 01, 2022 |
Kawailoa Solar Partnership LLC | Kawailoa Solar Project | ||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||
Ownership interest | 51% | |
Cash Equity Investor | Kawailoa Solar Project | ||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||
Ownership interest | 49% | |
Disposed of by Sale | Kawailoa Solar Partnership LLC | ||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||
Assets ownership sold (as a percentage) | 100% | |
Proceeds from sale of business | $ 9 | |
Removal of noncontrolling interest | $ 69 | |
Disposed of by Sale | Thermal | ||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||
Assets ownership sold (as a percentage) | 100% | |
Proceeds from sale of business | $ 1,460 | |
Transaction expenses | 18 | |
Gain on sale of asset | $ 1,290 |
Property, Plant and Equipment_2
Property, Plant and Equipment (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment, gross | $ 13,011 | $ 10,445 | |
Accumulated depreciation | (3,485) | (3,024) | |
Net property, plant and equipment | 9,526 | 7,421 | |
Depreciation expense | 514 | 502 | $ 499 |
Facilities and equipment | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment, gross | $ 11,426 | 9,992 | |
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 | 41 years | ||
Land and improvements | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment, gross | $ 365 | 293 | |
Construction in Progress | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment, gross | 1,220 | 160 | |
Construction in Progress | Accrued Liabilities | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment, gross | 72 | 9 | |
Construction in Progress | Conventional Generation | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment, gross | $ 21 | $ 17 |
Investments Accounted for by _3
Investments Accounted for by the Equity Method and Variable Interest Entities - Maximum Exposure to Loss Limited to Equity method investments (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Schedule of Equity Method Investments [Line Items] | ||
Investment Balance | $ 360 | $ 364 |
Avenal | ||
Schedule of Equity Method Investments [Line Items] | ||
Economic Interest | 50% | |
Investment Balance | $ 7 | |
Desert Sunlight | ||
Schedule of Equity Method Investments [Line Items] | ||
Economic Interest | 25% | |
Investment Balance | $ 224 | |
Elkhorn Ridge | ||
Schedule of Equity Method Investments [Line Items] | ||
Economic Interest | 66.70% | |
Investment Balance | $ 15 | |
Gen Conn | ||
Schedule of Equity Method Investments [Line Items] | ||
Economic Interest | 50% | |
Investment Balance | $ 79 | |
Rosie Central BESS | ||
Schedule of Equity Method Investments [Line Items] | ||
Economic Interest | 50% | |
Investment Balance | $ 28 | |
San Juan Mesa | ||
Schedule of Equity Method Investments [Line Items] | ||
Economic Interest | 75% | |
Investment Balance | $ 7 |
Investments Accounted for by _4
Investments Accounted for by the Equity Method and Variable Interest Entities - Narrative (Details) - USD ($) $ in Millions | 12 Months Ended | ||||||||
Dec. 06, 2023 | Jun. 30, 2015 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 29, 2023 | Oct. 31, 2023 | Aug. 30, 2023 | Feb. 17, 2023 | |
Schedule of Equity Method Investments [Line Items] | |||||||||
Retained earnings, undistributed earnings from equity method investees | $ 17 | $ 19 | |||||||
Payments to acquire equity method investments | 28 | 0 | $ 0 | ||||||
Long-term debt | 8,099 | ||||||||
Investment Balance | 360 | $ 364 | |||||||
Desert Sunlight | |||||||||
Schedule of Equity Method Investments [Line Items] | |||||||||
Carrying value basis difference | $ 122 | ||||||||
Ownership interest (as a percentage) | 25% | ||||||||
Investment Balance | $ 224 | ||||||||
Rosie Central BESS | |||||||||
Schedule of Equity Method Investments [Line Items] | |||||||||
Ownership interest (as a percentage) | 50% | ||||||||
Investment Balance | $ 28 | ||||||||
DGPV Funds | |||||||||
Schedule of Equity Method Investments [Line Items] | |||||||||
Investment Balance | $ 3 | ||||||||
Noncontrolling interest adjustment to additional paid in capital | $ 20 | ||||||||
DGPV Funds | DGPV 4 LLC | |||||||||
Schedule of Equity Method Investments [Line Items] | |||||||||
Ownership interest (as a percentage) | 100% | ||||||||
Alta TE Holdco LLC | |||||||||
Schedule of Equity Method Investments [Line Items] | |||||||||
Investment Balance | 10 | ||||||||
Noncontrolling interest adjustment to additional paid in capital | $ 37 | ||||||||
Alta TE Holdco LLC | Clearway Energy LLC | |||||||||
Schedule of Equity Method Investments [Line Items] | |||||||||
Ownership interest (as a percentage) | 100% | ||||||||
VP-Arica TargetCo LLC | |||||||||
Schedule of Equity Method Investments [Line Items] | |||||||||
Ownership interest (as a percentage) | 40% | ||||||||
Daggett Partnerships | |||||||||
Schedule of Equity Method Investments [Line Items] | |||||||||
Ownership interest (as a percentage) | 25% | ||||||||
Daggett TargetCo LLC | |||||||||
Schedule of Equity Method Investments [Line Items] | |||||||||
Ownership interest (as a percentage) | 25% | ||||||||
Desert Sunlight | |||||||||
Schedule of Equity Method Investments [Line Items] | |||||||||
Payments to acquire equity method investments | $ 285 | ||||||||
Business acquisition, consideration transferred, working capital | $ 181 | ||||||||
Long-term debt | $ 303 |
Investments Accounted for by _5
Investments Accounted for by the Equity Method and Variable Interest Entities - Summarized Financial Information of Equity Method Investments (Details) - USD ($) $ in Millions | 12 Months Ended | |||
May 31, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Schedule of Equity Method Investments [Line Items] | ||||
Operating revenues | $ 1,314 | $ 1,190 | $ 1,286 | |
Operating income (loss) | 263 | 1,470 | 267 | |
Net income (loss) | $ 8 | (14) | 1,060 | (75) |
Current assets | 1,560 | 1,276 | ||
Current liabilities | 906 | 617 | ||
Non-current liabilities | 8,800 | 7,662 | ||
GenConn | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Operating revenues | 51 | 50 | 55 | |
Operating income (loss) | 14 | 16 | 22 | |
Net income (loss) | 6 | 7 | 13 | |
Current assets | 39 | 39 | ||
Non-current assets | 294 | 312 | ||
Current liabilities | 15 | 16 | ||
Non-current liabilities | 162 | 170 | ||
Desert Sunlight | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Operating revenues | 202 | 203 | 205 | |
Operating income (loss) | 144 | 137 | 146 | |
Net income (loss) | 108 | 114 | 112 | |
Current assets | 80 | 79 | ||
Non-current assets | 1,131 | 1,175 | ||
Current liabilities | 61 | 61 | ||
Non-current liabilities | 776 | 824 | ||
Other | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Operating revenues | 43 | 52 | 49 | |
Operating income (loss) | 9 | 18 | 16 | |
Net income (loss) | 7 | 15 | $ 13 | |
Current assets | 19 | 22 | ||
Non-current assets | 135 | 157 | ||
Current liabilities | 13 | 12 | ||
Non-current liabilities | $ 81 | $ 91 |
Investments Accounted for by _6
Investments Accounted for by the Equity Method and Variable Interest Entities - VIEs that are Consolidated (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | $ 3,615 | $ 3,615 |
Property, plant and equipment | 9,526 | 7,421 |
Intangible assets | 2,374 | 2,565 |
Total Assets | 14,701 | 12,312 |
Total Liabilities | 9,706 | $ 8,279 |
Buckthorn Holdings, LLC | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 4 | |
Property, plant and equipment | 185 | |
Intangible assets | 0 | |
Total Assets | 189 | |
Total Liabilities | 12 | |
Noncontrolling interest | 15 | |
Net assets less noncontrolling interest | 162 | |
DGPV Funds | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 58 | |
Property, plant and equipment | 381 | |
Intangible assets | 1 | |
Total Assets | 440 | |
Total Liabilities | 50 | |
Noncontrolling interest | 3 | |
Net assets less noncontrolling interest | 387 | |
Langford TE Partnership LLC | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 23 | |
Property, plant and equipment | 115 | |
Intangible assets | 0 | |
Total Assets | 138 | |
Total Liabilities | 63 | |
Noncontrolling interest | 66 | |
Net assets less noncontrolling interest | 9 | |
Daggett Partnerships | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 167 | |
Property, plant and equipment | 988 | |
Intangible assets | 0 | |
Total Assets | 1,155 | |
Total Liabilities | 464 | |
Noncontrolling interest | 827 | |
Net assets less noncontrolling interest | (136) | |
Lighthouse Renewable Holdco LLC | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 68 | |
Property, plant and equipment | 415 | |
Intangible assets | 0 | |
Total Assets | 483 | |
Total Liabilities | 139 | |
Noncontrolling interest | 254 | |
Net assets less noncontrolling interest | 90 | |
Lighthouse Renewable Holdco 2 LLC | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 135 | |
Property, plant and equipment | 1,086 | |
Intangible assets | 2 | |
Total Assets | 1,223 | |
Total Liabilities | 447 | |
Noncontrolling interest | 590 | |
Net assets less noncontrolling interest | 186 | |
Oahu Solar LLC | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 38 | |
Property, plant and equipment | 157 | |
Intangible assets | 0 | |
Total Assets | 195 | |
Total Liabilities | 22 | |
Noncontrolling interest | 23 | |
Net assets less noncontrolling interest | 150 | |
Rattlesnake TE Holdco LLC | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 13 | |
Property, plant and equipment | 176 | |
Intangible assets | 0 | |
Total Assets | 189 | |
Total Liabilities | 17 | |
Noncontrolling interest | 77 | |
Net assets less noncontrolling interest | 95 | |
Rosie TargetCo LLC | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 298 | |
Property, plant and equipment | 507 | |
Intangible assets | 0 | |
Total Assets | 805 | |
Total Liabilities | 376 | |
Noncontrolling interest | 181 | |
Net assets less noncontrolling interest | 248 | |
VP-Arica TargetCo LLC | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 101 | |
Property, plant and equipment | 960 | |
Intangible assets | 0 | |
Total Assets | 1,061 | |
Total Liabilities | 834 | |
Noncontrolling interest | 67 | |
Net assets less noncontrolling interest | 160 | |
Wildorado TE Holdco LLC | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 20 | |
Property, plant and equipment | 194 | |
Intangible assets | 0 | |
Total Assets | 214 | |
Total Liabilities | 18 | |
Noncontrolling interest | 99 | |
Net assets less noncontrolling interest | 97 | |
Other | ||
Schedule of Equity Method Investments [Line Items] | ||
Other current and non-current assets | 24 | |
Property, plant and equipment | 238 | |
Intangible assets | 16 | |
Total Assets | 278 | |
Total Liabilities | 85 | |
Noncontrolling interest | 95 | |
Net assets less noncontrolling interest | $ 98 |
Fair Value of Financial Instr_3
Fair Value of Financial Instruments - Balance Sheet Grouping (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Carrying Amount | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term debt, including current portion | $ 8,102 | $ 6,874 |
Fair Value | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term debt, including current portion | 7,611 | 6,288 |
Fair Value | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term debt, including current portion | 1,939 | 1,834 |
Fair Value | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Long-term debt, including current portion | $ 5,672 | $ 4,454 |
Fair Value of Financial Instr_4
Fair Value of Financial Instruments - Recurring Fair Value Measurements (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | $ 123 | $ 89 | |
Derivative liabilities | 332 | 353 | |
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, | $ (6) | $ 28 | $ 19 |
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] | |||
Fair value of short term debt | $ 5 | ||
Fair value of long term debt | 325 | ||
Fair Value, Recurring | |||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | |||
Beginning balance | (336) | $ (154) | |
Settlements | 28 | 61 | |
Additions due to loss of NPNS exception | 0 | (22) | |
Total losses for the period included in earnings | (9) | (221) | |
Ending balance | (317) | (336) | (154) |
Change in unrealized losses included in earnings for derivatives and other financial instruments held as of December 31, | (9) | (221) | |
Level 2 | Fair Value, Recurring | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | 123 | 89 | |
Derivative liabilities | 2 | 0 | |
Level 3 | Fair Value, Recurring | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | 13 | 17 | |
Derivative liabilities | 330 | 353 | |
Energy-related commodity contracts | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | 2 | ||
Derivative liabilities | 330 | 353 | |
Energy-related commodity contracts | Level 2 | Fair Value, Recurring | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | 2 | 0 | |
Derivative liabilities | 0 | 0 | |
Energy-related commodity contracts | Level 3 | Fair Value, Recurring | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | 0 | 0 | |
Derivative liabilities | 330 | 353 | |
Interest rate contracts | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | 121 | 89 | |
Derivative liabilities | 2 | ||
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, | (17) | 100 | $ 53 |
Interest rate contracts | Level 2 | Fair Value, Recurring | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | 121 | 89 | |
Derivative liabilities | 2 | 0 | |
Interest rate contracts | Level 3 | Fair Value, Recurring | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | 0 | 0 | |
Derivative liabilities | 0 | 0 | |
Other Financial Instruments | Level 2 | Fair Value, Recurring | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | 0 | 0 | |
Other Financial Instruments | Level 3 | Fair Value, Recurring | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Derivative assets | $ 13 | $ 17 |
Fair Value of Financial Instr_5
Fair Value of Financial Instruments - Narrative (Details) $ in Millions | Dec. 31, 2023 USD ($) |
Fair Value Disclosures [Abstract] | |
Percent of derivative liabilities using level 3 fair value inputs | 99% |
Percent of financial instruments using level 3 fair value inputs | 100% |
Fair value assets, measured on recurring basis, valuation techniques, impact of credit reserve to fair value | $ 15 |
Fair Value of Financial Instr_6
Fair Value of Financial Instruments - Significant Unobservable Inputs (Details) - Fair Value, Recurring - Level 3 $ in Millions | Dec. 31, 2023 USD ($) $ / MWh MWh $ / BTU |
Low | Measurement Input, Commodity Forward Price | Valuation Technique, Option Model | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | $ / BTU | 1.25 |
High | Measurement Input, Commodity Forward Price | Valuation Technique, Option Model | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | $ / BTU | 13.69 |
Weighted Average | Measurement Input, Commodity Forward Price | Valuation Technique, Option Model | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | $ / BTU | 4.93 |
Long-term Power Commodity Contracts | Valuation Technique, Discounted Cash Flow | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset | $ | $ 0 |
Derivative liability | $ | $ 325 |
Long-term Power Commodity Contracts | Low | Measurement Input, Commodity Forward Price | Valuation Technique, Discounted Cash Flow | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | $ / MWh | 18.18 |
Long-term Power Commodity Contracts | High | Measurement Input, Commodity Forward Price | Valuation Technique, Discounted Cash Flow | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | $ / MWh | 81.62 |
Long-term Power Commodity Contracts | Weighted Average | Measurement Input, Commodity Forward Price | Valuation Technique, Discounted Cash Flow | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | $ / MWh | 39.91 |
Commodity Contracts | Measurement Input, Commodity Forward Price | Valuation Technique, Option Model | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset | $ | $ 0 |
Derivative liability | $ | $ 5 |
Commodity Contracts | Low | Measurement Input, Commodity Forward Price | Valuation Technique, Option Model | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | $ / MWh | (43.96) |
Commodity Contracts | High | Measurement Input, Commodity Forward Price | Valuation Technique, Option Model | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | $ / MWh | 343.61 |
Commodity Contracts | Weighted Average | Measurement Input, Commodity Forward Price | Valuation Technique, Option Model | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | $ / MWh | 64.34 |
Other Financial Instruments | Valuation Technique, Discounted Cash Flow | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset | $ | $ 13 |
Derivative liability | $ | $ 0 |
Other Financial Instruments | Low | Measurement Input, Commodity Forward Price | Valuation Technique, Discounted Cash Flow | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | MWh | 60,801 |
Other Financial Instruments | High | Measurement Input, Commodity Forward Price | Valuation Technique, Discounted Cash Flow | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | MWh | 121,602 |
Other Financial Instruments | Weighted Average | Measurement Input, Commodity Forward Price | Valuation Technique, Discounted Cash Flow | |
Fair Value Measurement Inputs and Valuation Techniques [Line Items] | |
Derivative asset/liability measurement input | MWh | 115,622 |
Accounting for Derivative Ins_3
Accounting for Derivative Instruments and Hedging Activities - Volume Buy/Sell of Company's Open Derivative Transactions (Details) $ in Millions | 3 Months Ended | 12 Months Ended | |
Mar. 31, 2023 MWh BTU | Dec. 31, 2023 USD ($) MWh BTU | Dec. 31, 2022 USD ($) | |
Long | Interest | |||
Derivative [Line Items] | |||
Notional amount | $ | $ 2,467 | $ 1,084 | |
Commodity Contracts | Short | Power | |||
Derivative [Line Items] | |||
Notional amount, energy measure | MWh | 18 | 23 | |
Commodity Contracts | Short | Natural Gas | |||
Derivative [Line Items] | |||
Notional amount, energy measure | BTU | 0 | 17 |
Accounting for Derivative Ins_4
Accounting for Derivative Instruments and Hedging Activities - FV of Derivatives (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Derivative [Line Items] | ||
Derivative assets | $ 123 | $ 89 |
Derivative liabilities | 332 | 353 |
Derivatives Designated as Cash Flow Hedges: | ||
Derivative [Line Items] | ||
Derivative assets | 19 | 25 |
Derivative liabilities | 2 | 0 |
Derivatives Not Designated as Cash Flow Hedges: | ||
Derivative [Line Items] | ||
Derivative assets | 104 | 64 |
Derivative liabilities | 330 | 353 |
Interest rate contracts current | Derivatives Designated as Cash Flow Hedges: | ||
Derivative [Line Items] | ||
Derivative assets | 7 | 7 |
Derivative liabilities | 0 | 0 |
Interest rate contracts current | Derivatives Not Designated as Cash Flow Hedges: | ||
Derivative [Line Items] | ||
Derivative assets | 33 | 19 |
Derivative liabilities | 0 | 0 |
Interest rate contracts long-term | Derivatives Designated as Cash Flow Hedges: | ||
Derivative [Line Items] | ||
Derivative assets | 12 | 18 |
Derivative liabilities | 2 | 0 |
Interest rate contracts long-term | Derivatives Not Designated as Cash Flow Hedges: | ||
Derivative [Line Items] | ||
Derivative assets | 69 | 45 |
Derivative liabilities | 0 | 0 |
Energy-related commodity contracts current | Derivatives Not Designated as Cash Flow Hedges: | ||
Derivative [Line Items] | ||
Derivative assets | 1 | 0 |
Derivative liabilities | 51 | 50 |
Energy-related commodity contracts long-term | Derivatives Not Designated as Cash Flow Hedges: | ||
Derivative [Line Items] | ||
Derivative assets | 1 | 0 |
Derivative liabilities | $ 279 | $ 303 |
Accounting for Derivative Ins_5
Accounting for Derivative Instruments and Hedging Activities - Offsetting Derivatives by Counterparty Master Agreement Level (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Derivative [Line Items] | ||
Derivative assets, gross | $ 123 | $ 89 |
Derivative liabilities, gross | (332) | (353) |
Fair value of gross derivative assets/(liabilities), net | (209) | (264) |
Derivative instruments | 0 | 0 |
Net amount | (209) | (264) |
Energy-related commodity contracts | ||
Derivative [Line Items] | ||
Derivative assets, gross | 2 | |
Derivative instruments, assets | 0 | |
Net amount | 2 | |
Derivative liabilities, gross | (330) | (353) |
Derivative instruments, liabilities | 0 | 0 |
Derivative Liabilities, Net Amount | (330) | (353) |
Fair value of gross derivative assets/(liabilities), net | (328) | (353) |
Derivative instruments | 0 | 0 |
Net amount | (328) | (353) |
Interest rate contracts | ||
Derivative [Line Items] | ||
Derivative assets, gross | 121 | 89 |
Derivative instruments, assets | (2) | 0 |
Net amount | 119 | 89 |
Derivative liabilities, gross | (2) | |
Derivative instruments, liabilities | 2 | |
Derivative Liabilities, Net Amount | 0 | |
Fair value of gross derivative assets/(liabilities), net | 119 | 89 |
Derivative instruments | 0 | 0 |
Net amount | $ 119 | $ 89 |
Accounting for Derivative Ins_6
Accounting for Derivative Instruments and Hedging Activities - AOCI (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Derivatives used in Net Investment Hedge, Net of Tax [Roll Forward] | |||
Beginning balance | $ 4,026 | $ 3,300 | $ 2,715 |
Mark-to-market of cash flow hedge accounting contracts | (6) | 28 | 19 |
Ending balance | 4,994 | 4,026 | 3,300 |
Accumulated other comprehensive income | 7 | 9 | |
Income expected to be realized from OCI during the next 12 months, net of income tax expense of $1 | 4 | ||
Accumulated OCL ending balance, income tax benefit | 2 | 3 | (2) |
Losses expected to be realized from OCL during the next 12 months, income tax benefit | 1 | ||
Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent | |||
Derivatives used in Net Investment Hedge, Net of Tax [Roll Forward] | |||
Beginning balance | 24 | (11) | (30) |
Ending balance | 18 | 24 | (11) |
Accumulated Foreign Currency Adjustment Including Portion Attributable to Noncontrolling Interest | |||
Derivatives used in Net Investment Hedge, Net of Tax [Roll Forward] | |||
Reclassified from accumulated OCI (OCL) to income due to realization of previously deferred amounts | (4) | 4 | 8 |
Mark-to-market of cash flow hedge accounting contracts | (2) | 24 | 11 |
Accumulated Foreign Currency Adjustment Including Portion Attributable to Noncontrolling Interest | Capistrano Wind Portfolio | |||
Derivatives used in Net Investment Hedge, Net of Tax [Roll Forward] | |||
Capistrano Wind Portfolio Acquisition | 0 | 7 | 0 |
Non-controlling Interest | |||
Derivatives used in Net Investment Hedge, Net of Tax [Roll Forward] | |||
Beginning balance | 1,792 | 1,466 | 890 |
Ending balance | 2,893 | 1,792 | 1,466 |
Accumulated other comprehensive income | 11 | 15 | (5) |
Non-controlling Interest | Capistrano Wind Portfolio | |||
Derivatives used in Net Investment Hedge, Net of Tax [Roll Forward] | |||
Capistrano Wind Portfolio Acquisition | 3 | ||
Accumulated Other Comprehensive (Loss) Income | |||
Derivatives used in Net Investment Hedge, Net of Tax [Roll Forward] | |||
Beginning balance | 9 | (6) | (14) |
Ending balance | 7 | 9 | (6) |
Accumulated other comprehensive income | 7 | $ 9 | $ (6) |
Clearway Energy, Inc. | Capistrano Wind Portfolio | |||
Derivatives used in Net Investment Hedge, Net of Tax [Roll Forward] | |||
Capistrano Wind Portfolio Acquisition | $ 4 |
Accounting for Derivative Ins_7
Accounting for Derivative Instruments and Hedging Activities - Impact of Statement of Operations (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Derivative Instruments, Gain (Loss) [Line Items] | |||
Unrealized gain (loss) on derivatives, net of tax | $ (6) | $ 28 | $ 19 |
Interest rate contracts | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Unrealized gain (loss) on derivatives, net of tax | (17) | 100 | 53 |
Energy-Related Commodity Contracts - Operating Revenue | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Unrealized gain (loss) on derivatives, net of tax | 23 | (174) | (83) |
Energy-Related Commodity Contracts - Cost of Operation | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Unrealized gain (loss) on derivatives, net of tax | $ 2 | $ 0 | $ 0 |
Intangible Assets - Components
Intangible Assets - Components Subject to Amortization (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Finite-lived Intangible Assets [Roll Forward] | |||
Net carrying amount beginning balance | $ 3,383 | $ 3,442 | $ 3,104 |
Net carrying amount ending balance | 3,383 | 3,442 | 3,104 |
Less accumulated amortization | (1,009) | (877) | |
Ending balance | 2,374 | $ 2,565 | |
Weighted average useful life of acquired intangible | 10 years | ||
Walnut Creek | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Expiration | 50 | ||
Acquisitions | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Acquisition | $ 336 | ||
Other Acquisitions | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Other | (9) | 2 | |
PPAs | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Net carrying amount beginning balance | 3,265 | 3,321 | 2,985 |
Net carrying amount ending balance | 3,265 | 3,321 | 2,985 |
Less accumulated amortization | (962) | (833) | |
Ending balance | 2,303 | 2,488 | |
PPAs | Walnut Creek | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Expiration | 50 | ||
PPAs | Acquisitions | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Acquisition | 336 | ||
PPAs | Other Acquisitions | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Other | (6) | 0 | |
Leasehold Rights | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Net carrying amount beginning balance | 86 | 86 | 86 |
Net carrying amount ending balance | 86 | 86 | 86 |
Less accumulated amortization | (38) | (34) | |
Ending balance | 48 | 52 | |
Leasehold Rights | Walnut Creek | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Expiration | 0 | ||
Leasehold Rights | Acquisitions | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Acquisition | 0 | ||
Leasehold Rights | Other Acquisitions | |||
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 |
Net carrying amount ending balance | 17 | 17 | 17 |
Less accumulated amortization | (4) | (4) | |
Ending balance | 13 | 13 | |
Emission Allowances | Walnut Creek | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Expiration | 0 | ||
Emission Allowances | Acquisitions | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Acquisition | 0 | ||
Emission Allowances | Other Acquisitions | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Other | 0 | 0 | |
Other | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Net carrying amount beginning balance | 15 | 18 | 16 |
Net carrying amount ending balance | 15 | 18 | $ 16 |
Less accumulated amortization | (5) | (6) | |
Ending balance | 10 | 12 | |
Other | Walnut Creek | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Expiration | 0 | ||
Other | Acquisitions | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Acquisition | 0 | ||
Other | Other Acquisitions | |||
Finite-lived Intangible Assets [Roll Forward] | |||
Other | $ (3) | $ 2 |
Intangible Assets - Narrative (
Intangible Assets - Narrative (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Goodwill and Intangible Assets Disclosure [Abstract] | |||
Amortization expense | $ 186 | $ 174 | $ 143 |
Contract amortization expense | $ 181 | $ 168 | $ 135 |
Intangible Assets - Schedule Fu
Intangible Assets - Schedule Future Amortization Expense for Intangibles (Details) $ in Millions | Dec. 31, 2023 USD ($) |
Goodwill and Intangible Assets Disclosure [Abstract] | |
2024 | $ 184 |
2025 | 184 |
2026 | 184 |
2027 | 183 |
2028 | $ 183 |
Asset Impairments (Details)
Asset Impairments (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Impaired Long-Lived Assets Held and Used [Line Items] | |||
Impairment losses | $ 12 | $ 16 | $ 6 |
Property, Plant and Equipment | |||
Impaired Long-Lived Assets Held and Used [Line Items] | |||
Impairment losses | $ 16 | $ 6 |
Long-term Debt - Short and Long
Long-term Debt - Short and Long-term Borrowings (Details) - USD ($) | 12 Months Ended | |||
Mar. 15, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | Mar. 16, 2022 | |
Debt Instrument [Line Items] | ||||
Long-term debt | $ 8,099,000,000 | $ 6,870,000,000 | ||
Less current maturities | (558,000,000) | (322,000,000) | ||
Less net debt issuance costs | (65,000,000) | (61,000,000) | ||
Add premiums | 3,000,000 | 4,000,000 | ||
Total long-term debt | 7,479,000,000 | 6,491,000,000 | ||
2028 Senior Notes | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 850,000,000 | 850,000,000 | ||
Interest rate, percentage | 475% | |||
2031 Senior Notes | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 925,000,000 | 925,000,000 | ||
Interest rate, percentage | 375% | |||
2032 Senior Notes | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 350,000,000 | 350,000,000 | ||
Interest rate, percentage | 375% | |||
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 0 | 0 | ||
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 0.10% | 1.85% | ||
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 246,000,000 | |||
Agua Caliente Solar LLC, due 2037 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 612,000,000 | 649,000,000 | ||
Agua Caliente Solar LLC, due 2037 | Minimum | ||||
Debt Instrument [Line Items] | ||||
Interest rate, percentage | 2.395% | |||
Agua Caliente Solar LLC, due 2037 | Maximum | ||||
Debt Instrument [Line Items] | ||||
Interest rate, percentage | 3.633% | |||
Agua Caliente Solar LLC, due 2037 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 45,000,000 | |||
Alta Wind Asset Management LLC, due 2031 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 11,000,000 | 12,000,000 | ||
Alta Wind Asset Management LLC, due 2031 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 2.775% | |||
Alta Wind Asset Management LLC, due 2031 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 0 | |||
Alta Wind I-V lease financing arrangements, due 2034 and 2035 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 660,000,000 | 709,000,000 | ||
Alta Wind I-V lease financing arrangements, due 2034 and 2035 | Minimum | ||||
Debt Instrument [Line Items] | ||||
Interest rate, percentage | 5.696% | |||
Alta Wind I-V lease financing arrangements, due 2034 and 2035 | Maximum | ||||
Debt Instrument [Line Items] | ||||
Interest rate, percentage | 7.015% | |||
Alta Wind I-V lease financing arrangements, due 2034 and 2035 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 67,000,000 | |||
Alta Wind Realty Investments LLC, due 2031 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 20,000,000 | 22,000,000 | ||
Interest rate, percentage | 700% | |||
Alta Wind Realty Investments LLC, due 2031 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 0 | |||
Borrego, due 2024 and 2038 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | 48,000,000 | 51,000,000 | ||
Borrego, due 2024 and 2038 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | 4,000,000 | |||
Broken Bow, due 2031 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 41,000,000 | 45,000,000 | ||
Broken Bow, due 2031 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 2.10% | |||
Broken Bow, due 2031 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 6,000,000 | |||
Buckthorn Solar, due 2025 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 116,000,000 | 119,000,000 | ||
Buckthorn Solar, due 2025 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 2.10% | |||
Buckthorn Solar, due 2025 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 20,000,000 | |||
Carlsbad Energy Holdings LLC, due 2027 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 93,000,000 | 115,000,000 | ||
Carlsbad Energy Holdings LLC, due 2027 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.90% | |||
Carlsbad Energy Holdings LLC, due 2027 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 63,000,000 | |||
Carlsbad Energy Holdings LLC, due 2038 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 407,000,000 | 407,000,000 | ||
Interest rate, percentage | 412% | |||
Carlsbad Energy Holdings LLC, due 2038 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 0 | |||
Carlsbad Holdco, LLC, due 2038 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 195,000,000 | 197,000,000 | ||
Interest rate, percentage | 421% | |||
Carlsbad Holdco, LLC, due 2038 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 5,000,000 | |||
Cedro Hill, due 2024 and 2029 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 165,000,000 | 82,000,000 | ||
Cedro Hill, due 2024 and 2029 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 137.50% | |||
Cedro Hill, due 2024 and 2029 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 0 | |||
Crofton Bluffs, due 2031 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 27,000,000 | 29,000,000 | ||
Crofton Bluffs, due 2031 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 2.10% | |||
Crofton Bluffs, due 2031 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 3,000,000 | |||
CVSR, due 2037 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 601,000,000 | 627,000,000 | ||
CVSR, due 2037 | Minimum | ||||
Debt Instrument [Line Items] | ||||
Interest rate, percentage | 2.339% | |||
CVSR, due 2037 | Maximum | ||||
Debt Instrument [Line Items] | ||||
Interest rate, percentage | 3.775% | |||
CVSR, due 2037 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 0 | |||
CVSR Holdco Notes, due 2037 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 152,000,000 | 160,000,000 | ||
Interest rate, percentage | 468% | |||
CVSR Holdco Notes, due 2037 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 12,000,000 | |||
Daggett 2, due 2028 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 156,000,000 | 0 | ||
Daggett 2, due 2028 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.762% | |||
Daggett 2, due 2028 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 36,000,000 | |||
Daggett 3, due 2028 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 217,000,000 | 0 | ||
Daggett 3, due 2028 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.762% | |||
Daggett 3, due 2028 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 43,000,000 | |||
DG-CS Master Borrower LLC, due 2040 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 385,000,000 | 413,000,000 | ||
Interest rate, percentage | 351% | |||
DG-CS Master Borrower LLC, due 2040 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 30,000,000 | |||
Mililani I, due 2027 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 0 | 47,000,000 | ||
Mililani I, due 2027 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.60% | |||
Mililani I, due 2027 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 0 | |||
Mililani Class B Holdco, Due 2028 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 92,000,000 | 0 | ||
Mililani Class B Holdco, Due 2028 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.60% | |||
Mililani Class B Holdco, Due 2028 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 18,000,000 | |||
NIMH Solar, due 2024 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 148,000,000 | 163,000,000 | ||
NIMH Solar, due 2024 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 2.275% | |||
NIMH Solar, due 2024 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 10,000,000 | |||
Oahu Solar Holdings LLC, due 2026 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 81,000,000 | 83,000,000 | ||
Oahu Solar Holdings LLC, due 2026 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.525% | |||
Oahu Solar Holdings LLC, due 2026 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 9,000,000 | |||
Rosie Class B LLC, due 2024 and 2029 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 347,000,000 | 76,000,000 | ||
Rosie Class B LLC, due 2024 and 2029 | Minimum | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.25% | |||
Rosie Class B LLC, due 2024 and 2029 | Maximum | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 137.50% | |||
Rosie Class B LLC, due 2024 and 2029 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 24,000,000 | |||
Texas Solar Nova 1, due 2028 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 102,000,000 | 0 | ||
Texas Solar Nova 1, due 2028 | Minimum | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.75% | |||
Texas Solar Nova 1, due 2028 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 55,000,000 | |||
Utah Solar Portfolio, due 2036 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 242,000,000 | 257,000,000 | ||
Interest rate, percentage | 359% | |||
Utah Solar Portfolio, due 2036 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 155,000,000 | |||
Viento Funding II, LLC, due 2029 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 175,000,000 | 184,000,000 | $ 190,000,000 | |
Viento Funding II, LLC, due 2029 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.475% | |||
Viento Funding II, LLC, due 2029 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 25,000,000 | |||
Victory Pass and Arica, due 2024 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 757,000,000 | 0 | ||
Victory Pass and Arica, due 2024 | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.125% | |||
Victory Pass and Arica, due 2024 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 5,000,000 | |||
Waiawa, due 2028 | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 0 | 97,000,000 | ||
Waiawa, due 2028 | Minimum | Secured Overnight Financing Rate (SOFR) | ||||
Debt Instrument [Line Items] | ||||
Basis spread on variable rate | 1.60% | |||
Waiawa, due 2028 | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | $ 0 | |||
Other | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | 124,000,000 | 201,000,000 | ||
Other | Letter of Credit | ||||
Debt Instrument [Line Items] | ||||
Letters of credit outstanding | 63,000,000 | |||
Subtotal non-recourse project-level debt | ||||
Debt Instrument [Line Items] | ||||
Long-term debt | $ 5,974,000,000 | $ 4,745,000,000 |
Long-term Debt - Narrative (Det
Long-term Debt - Narrative (Details) - USD ($) | 12 Months Ended | |||||||||||||||||||||||||||
Dec. 28, 2023 | Dec. 22, 2023 | Dec. 18, 2023 | Dec. 12, 2023 | Dec. 01, 2023 | Nov. 01, 2023 | Oct. 31, 2023 | Aug. 31, 2023 | Aug. 30, 2023 | Jun. 30, 2023 | Mar. 30, 2023 | Mar. 15, 2023 | Feb. 17, 2023 | Dec. 15, 2022 | Dec. 07, 2022 | Oct. 04, 2022 | Oct. 03, 2022 | May 03, 2022 | Mar. 26, 2022 | Mar. 25, 2022 | Mar. 16, 2022 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Sep. 30, 2023 | Jul. 03, 2023 | Aug. 22, 2022 | Nov. 30, 2021 | |
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 8,099,000,000 | $ 6,870,000,000 | ||||||||||||||||||||||||||
Proceeds from the revolving credit facility | 0 | 80,000,000 | $ 622,000,000 | |||||||||||||||||||||||||
Capital expenditures | 157,000,000 | 56,000,000 | ||||||||||||||||||||||||||
Net debt issuance costs | 65,000,000 | 61,000,000 | ||||||||||||||||||||||||||
Contributions from noncontrolling interests, net of distributions | 1,028,000,000 | 60,000,000 | 967,000,000 | |||||||||||||||||||||||||
Investment Balance | 360,000,000 | 364,000,000 | ||||||||||||||||||||||||||
Removed related noncontrolling interest balance | 10,000,000 | |||||||||||||||||||||||||||
Loss on debt extinguishment | (6,000,000) | (2,000,000) | $ (53,000,000) | |||||||||||||||||||||||||
Rosie Central BESS | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Investment Balance | 28,000,000 | |||||||||||||||||||||||||||
Rosie Central BESS | Rosie Class B LLC | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Investment Balance | $ 18,000,000 | |||||||||||||||||||||||||||
Texas Solar Nova 1 | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 18,000,000 | |||||||||||||||||||||||||||
Long-term debt, additions | 12,000,000 | |||||||||||||||||||||||||||
Payments for other fees | 5,000,000 | |||||||||||||||||||||||||||
Texas Solar Nova 1 | CEG | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Remaining balance to distribute | 9,000,000 | |||||||||||||||||||||||||||
Cedro Hill Repowering | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Aggregate principal amount repurchased | $ 72,000,000 | |||||||||||||||||||||||||||
Long-term debt | 254,000,000 | |||||||||||||||||||||||||||
Proceeds from the revolving credit facility | 165,000,000 | |||||||||||||||||||||||||||
Remaining balance to distribute | 55,000,000 | |||||||||||||||||||||||||||
Proceeds from debt | 27,000,000 | |||||||||||||||||||||||||||
Capital expenditures | 3,000,000 | |||||||||||||||||||||||||||
Net debt issuance costs | 4,000,000 | |||||||||||||||||||||||||||
Payments for other fees | $ 4,000,000 | |||||||||||||||||||||||||||
Victory Pass and Arica Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 864,000,000 | |||||||||||||||||||||||||||
Unamortized debt issuance costs | 4,000,000 | |||||||||||||||||||||||||||
Victory Pass and Arica Drop Down | Tax Equity Investors | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Contributions from noncontrolling interests, net of distributions | 100,000,000 | |||||||||||||||||||||||||||
Daggett 2 Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 308,000,000 | |||||||||||||||||||||||||||
Unamortized debt issuance costs | 3,000,000 | |||||||||||||||||||||||||||
Expected contributions upon substantial completion | $ 202,000,000 | |||||||||||||||||||||||||||
Payments for other fees | 1,000,000 | |||||||||||||||||||||||||||
Daggett 2 Drop Down | CEG | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Remaining balance to distribute | 91,000,000 | |||||||||||||||||||||||||||
Daggett 2 Drop Down | Tax Equity Investors | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Contributions from noncontrolling interests, net of distributions | 120,000,000 | |||||||||||||||||||||||||||
Rosamond Central Solar Project | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 77,000,000 | 265,000,000 | ||||||||||||||||||||||||||
Net debt issuance costs | 5,000,000 | |||||||||||||||||||||||||||
Rosamond Central Solar Project | Rosie Central BESS | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Repayment of partial loan amount | $ 70,000,000 | |||||||||||||||||||||||||||
Daggett 3 Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 480,000,000 | |||||||||||||||||||||||||||
Unamortized debt issuance costs | 5,000,000 | |||||||||||||||||||||||||||
Expected contributions upon substantial completion | 252,000,000 | |||||||||||||||||||||||||||
Payments for other fees | 7,000,000 | |||||||||||||||||||||||||||
Daggett 3 Drop Down | CEG | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Remaining balance to distribute | 45,000,000 | |||||||||||||||||||||||||||
Payments for other fees | 54,000,000 | |||||||||||||||||||||||||||
Removed related noncontrolling interest balance | 22,000,000 | |||||||||||||||||||||||||||
Daggett 3 Drop Down | Tax Equity Investors | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Contributions from noncontrolling interests, net of distributions | 69,000,000 | |||||||||||||||||||||||||||
Daggett 3 Drop Down | Sponsor Equity Bridge Loan | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Payments for other fees | 8,000,000 | |||||||||||||||||||||||||||
Waiawa | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Payments for other fees | $ 1,000,000 | |||||||||||||||||||||||||||
Waiawa | CEG | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Contributions from noncontrolling interests, net of distributions | 17,000,000 | |||||||||||||||||||||||||||
Expected contributions upon substantial completion | 8,000,000 | |||||||||||||||||||||||||||
Payments to fund project reserve accounts | $ 16,000,000 | |||||||||||||||||||||||||||
Waiawa | Sponsor Equity Bridge Loan | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Payments for other fees | 2,000,000 | |||||||||||||||||||||||||||
Mililani I Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 100,000,000 | |||||||||||||||||||||||||||
Unamortized debt issuance costs | 3,000,000 | |||||||||||||||||||||||||||
Contributions from noncontrolling interests, net of distributions | $ 18,000,000 | |||||||||||||||||||||||||||
Payments for other fees | 4,000,000 | |||||||||||||||||||||||||||
Mililani I Drop Down | CEG | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Payments to fund project reserve accounts | 15,000,000 | |||||||||||||||||||||||||||
Removed related noncontrolling interest balance | 11,000,000 | |||||||||||||||||||||||||||
Mililani I Drop Down | Tax Equity Investors | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Expected contributions upon substantial completion | 42,000,000 | |||||||||||||||||||||||||||
Payments to fund project reserve accounts | 15,000,000 | |||||||||||||||||||||||||||
Mililani I Drop Down | Sponsor Equity Bridge Loan | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Payments for other fees | 2,000,000 | |||||||||||||||||||||||||||
Term Loan | Waiawa | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt, additions | 47,000,000 | |||||||||||||||||||||||||||
Term Loan | Mililani I Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt, additions | 48,000,000 | |||||||||||||||||||||||||||
Sponsor Equity Bridge Loan | Victory Pass and Arica Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 483,000,000 | |||||||||||||||||||||||||||
Partial payment | 133,000,000 | |||||||||||||||||||||||||||
Sponsor Equity Bridge Loan | Daggett 3 Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 75,000,000 | |||||||||||||||||||||||||||
Sponsor Equity Bridge Loan | Waiawa | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 27,000,000 | |||||||||||||||||||||||||||
Unamortized debt issuance costs | 1,000,000 | |||||||||||||||||||||||||||
Sponsor Equity Bridge Loan | Waiawa | Cash Equity Investor | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Repayment of debt, acquired in asset acquisition | 12,000,000 | |||||||||||||||||||||||||||
Sponsor Equity Bridge Loan | Mililani I Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 27,000,000 | |||||||||||||||||||||||||||
Sponsor Equity Bridge Loan | Mililani I Drop Down | Cash Equity Investor | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Repayment of debt, acquired in asset acquisition | 14,000,000 | |||||||||||||||||||||||||||
Tax Equity Bridge Loan | Victory Pass and Arica Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 385,000,000 | |||||||||||||||||||||||||||
Long-term debt, additions | $ 22,000,000 | |||||||||||||||||||||||||||
Tax Equity Bridge Loan | Daggett 2 Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 204,000,000 | 204,000,000 | ||||||||||||||||||||||||||
Tax Equity Bridge Loan | Rosamond Central Solar Project | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 188,000,000 | 155,000,000 | ||||||||||||||||||||||||||
Tax Equity Bridge Loan | Daggett 3 Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 229,000,000 | 229,000,000 | ||||||||||||||||||||||||||
Tax Equity Bridge Loan | Waiawa | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Aggregate principal amount repurchased | 55,000,000 | |||||||||||||||||||||||||||
Long-term debt | 55,000,000 | |||||||||||||||||||||||||||
Tax Equity Bridge Loan | Mililani I Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 60,000,000 | 60,000,000 | ||||||||||||||||||||||||||
Construction Loans | Texas Solar Nova 1 | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt, additions | 102,000,000 | |||||||||||||||||||||||||||
Construction Loans | Daggett 2 Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 36,000,000 | $ 107,000,000 | ||||||||||||||||||||||||||
Long-term debt, additions | 156,000,000 | $ 49,000,000 | ||||||||||||||||||||||||||
Proceeds | $ 10,000,000 | |||||||||||||||||||||||||||
Construction Loans | Rosamond Central Solar Project | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 115,000,000 | 115,000,000 | ||||||||||||||||||||||||||
Construction Loans | Daggett 3 Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 40,000,000 | $ 181,000,000 | ||||||||||||||||||||||||||
Long-term debt, additions | $ 36,000,000 | $ 217,000,000 | ||||||||||||||||||||||||||
Construction Loans | Capistrano Wind Portfolio | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Unamortized debt issuance costs | $ 2,000,000 | |||||||||||||||||||||||||||
Debt instrument, face amount | $ 164,000,000 | |||||||||||||||||||||||||||
Construction Loans | Waiawa | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 22,000,000 | |||||||||||||||||||||||||||
Construction Loans | Mililani I Drop Down | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 16,000,000 | |||||||||||||||||||||||||||
Long-term debt, additions | $ 32,000,000 | |||||||||||||||||||||||||||
El Segundo Energy Center, due 2023 | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Aggregate principal amount repurchased | $ 130,000,000 | |||||||||||||||||||||||||||
Tax Equity Investors | Texas Solar Nova 1 | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 148,000,000 | |||||||||||||||||||||||||||
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | 0 | 0 | ||||||||||||||||||||||||||
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility | Line of Credit | Revolving Credit Facility | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Bridge credit agreement, borrowing amount | $ 700,000,000 | |||||||||||||||||||||||||||
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility | Line of Credit | Letter of Credit | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Bridge credit agreement, borrowing amount | $ 594,000,000 | |||||||||||||||||||||||||||
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility | Letter of Credit | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Letters of credit outstanding | $ 246,000,000 | |||||||||||||||||||||||||||
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility | Secured Overnight Financing Rate (SOFR) | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Basis spread on variable rate | 0.10% | 1.85% | ||||||||||||||||||||||||||
Revolving Credit Facility | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Outstanding borrowings | $ 0 | |||||||||||||||||||||||||||
Bridge Loan, due 2022 | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Aggregate principal amount repurchased | $ 335,000,000 | |||||||||||||||||||||||||||
Bridge Loan, due 2022 | SOFR | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 335,000,000 | |||||||||||||||||||||||||||
Rosamond Central Solar Project | Line of Credit | Letter of Credit | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Bridge credit agreement, borrowing amount | $ 41,000,000 | |||||||||||||||||||||||||||
Rosamond Central Solar Project | Construction Loans | Rosamond Central Solar Project | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt, term | 5 years | |||||||||||||||||||||||||||
Clearway Renew LLC | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Bridge credit agreement, borrowing amount | 174,000,000 | |||||||||||||||||||||||||||
Interest rate, percentage | 9% | |||||||||||||||||||||||||||
Waiawa | Waiawa | Tax Equity Investors | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Expected contributions upon substantial completion | 41,000,000 | |||||||||||||||||||||||||||
Waiawa | Construction Loans | Waiawa | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Aggregate principal amount repurchased | $ 10,000,000 | |||||||||||||||||||||||||||
Long-term debt, additions | $ 25,000,000 | |||||||||||||||||||||||||||
Mililani Class B | Construction Loans | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 7,000,000 | |||||||||||||||||||||||||||
Viento Funding II, LLC, due 2029 | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Long-term debt | $ 190,000,000 | 175,000,000 | $ 184,000,000 | |||||||||||||||||||||||||
Viento Funding II, LLC, due 2029 | Letter of Credit | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Letters of credit outstanding | $ 25,000,000 | |||||||||||||||||||||||||||
Debt instrument, face amount | 35,000,000 | |||||||||||||||||||||||||||
Viento Funding II, LLC, due 2029 | Secured Overnight Financing Rate (SOFR) | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Basis spread on variable rate | 1.475% | |||||||||||||||||||||||||||
Laredo Ridge, Due 2028; Tapestry Wind, LLC, Due 2031; and Viento Funding II, LLC, Due 2023 | ||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||||||||
Aggregate principal amount repurchased | 186,000,000 | |||||||||||||||||||||||||||
Loss on debt extinguishment | $ 2,000,000 |
Long-term Debt - Interest Rate
Long-term Debt - Interest Rate Swaps (Details) - Interest Rate Swap $ in Millions | Dec. 31, 2023 USD ($) |
Debt Instrument [Line Items] | |
Notional amount | $ 2,467 |
Avra Valley | Maturity - January 31, 2031 | |
Debt Instrument [Line Items] | |
Percentage of principal | 85% |
Fixed interest rate | 2.20% |
Notional amount | $ 29 |
AWAM | Maturity - May 15, 2031 | |
Debt Instrument [Line Items] | |
Percentage of principal | 100% |
Fixed interest rate | 2.22% |
Notional amount | $ 11 |
Borrego | Maturity - December 31, 2024 | |
Debt Instrument [Line Items] | |
Percentage of principal | 100% |
Fixed interest rate | 0.21% |
Notional amount | $ 3 |
Broken Bow | |
Debt Instrument [Line Items] | |
Percentage of principal | 90% |
Notional amount | $ 37 |
Buckthorn Solar | Maturity - December 31, 2041 | |
Debt Instrument [Line Items] | |
Percentage of principal | 80% |
Notional amount | $ 93 |
Carlsbad Energy Holdings | Maturity - September 30, 2027 | |
Debt Instrument [Line Items] | |
Percentage of principal | 100% |
Notional amount | $ 93 |
Cedro Hill | |
Debt Instrument [Line Items] | |
Percentage of principal | 86% |
Notional amount | $ 142 |
Crofton Bluffs | |
Debt Instrument [Line Items] | |
Percentage of principal | 90% |
Notional amount | $ 24 |
Daggett 2 | Maturity - March 31, 2043 | |
Debt Instrument [Line Items] | |
Percentage of principal | 90% |
Fixed interest rate | 2.22% |
Notional amount | $ 141 |
Daggett 3 | Maturity - September 30, 2043 | |
Debt Instrument [Line Items] | |
Percentage of principal | 86% |
Fixed interest rate | 1.91% |
Notional amount | $ 186 |
Kansas South | Maturity - December 31, 2030 | |
Debt Instrument [Line Items] | |
Percentage of principal | 75% |
Fixed interest rate | 1.93% |
Notional amount | $ 12 |
Mililani Class B | |
Debt Instrument [Line Items] | |
Percentage of principal | 98% |
Notional amount | $ 90 |
NIMH Solar LLC | |
Debt Instrument [Line Items] | |
Percentage of principal | 100% |
Notional amount | $ 148 |
Oahu Solar | Maturity - October 31, 2040 | |
Debt Instrument [Line Items] | |
Percentage of principal | 96% |
Fixed interest rate | 2.47% |
Notional amount | $ 77 |
Rosie Class B | |
Debt Instrument [Line Items] | |
Percentage of principal | 53% |
Notional amount | $ 182 |
South Trent | Maturity - June 30, 2028 | |
Debt Instrument [Line Items] | |
Percentage of principal | 90% |
Notional amount | $ 22 |
Texas Solar Nova 1 | Maturity - June 30, 2043 | |
Debt Instrument [Line Items] | |
Percentage of principal | 94% |
Fixed interest rate | 2.92% |
Notional amount | $ 97 |
Viento Funding II | Maturity - December 31, 2032 | |
Debt Instrument [Line Items] | |
Percentage of principal | 90% |
Fixed interest rate | 2.53% |
Notional amount | $ 158 |
Victory Pass and Arica, due 2024 | Maturity - January 31, 2024 | |
Debt Instrument [Line Items] | |
Percentage of principal | 122% |
Fixed interest rate | 4.18% |
Notional amount | $ 922 |
Long-term Debt - Annual Maturit
Long-term Debt - Annual Maturities (Details) $ in Millions | Dec. 31, 2023 USD ($) |
Debt Disclosure [Abstract] | |
2024 | $ 1,669 |
2025 | 371 |
2026 | 351 |
2027 | 288 |
2028 | 1,662 |
Thereafter | 3,758 |
Total | 8,099 |
Debt, Current | $ 1,110 |
Earnings Per Share - Schedule o
Earnings Per Share - Schedule of Reconciliation of Basic and Diluted Earnings (Loss) Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Basic and diluted income per share attributable to Clearway Energy, Inc. common stockholders | |||
Net income attributable to Clearway Energy, Inc. | $ 79 | $ 582 | $ 51 |
Weighted average number of common shares outstanding - diluted (in shares) | 35 | 35 | 35 |
Earnings per weighted average common share - basic (in dollars per share) | $ 0.67 | $ 4.99 | $ 0.44 |
Earnings per weighted average common share - diluted (in dollars per share) | $ 0.67 | $ 4.99 | $ 0.44 |
Common Class A | |||
Basic and diluted income per share attributable to Clearway Energy, Inc. common stockholders | |||
Net income attributable to Clearway Energy, Inc. | $ 23 | $ 172 | $ 15 |
Weighted average number of shares outstanding - basic (in shares) | 35 | 35 | 35 |
Weighted average number of common shares outstanding - diluted (in shares) | 35 | 35 | 35 |
Earnings per weighted average common share - basic (in dollars per share) | $ 0.67 | $ 4.99 | $ 0.44 |
Earnings per weighted average common share - diluted (in dollars per share) | $ 0.67 | $ 4.99 | $ 0.44 |
Common Class C | |||
Basic and diluted income per share attributable to Clearway Energy, Inc. common stockholders | |||
Net income attributable to Clearway Energy, Inc. | $ 56 | $ 410 | $ 36 |
Weighted average number of shares outstanding - basic (in shares) | 82 | 82 | 82 |
Weighted average number of common shares outstanding - diluted (in shares) | 82 | 82 | 82 |
Earnings per weighted average common share - basic (in dollars per share) | $ 0.67 | $ 4.99 | $ 0.44 |
Earnings per weighted average common share - diluted (in dollars per share) | $ 0.67 | $ 4.99 | $ 0.44 |
Stockholders' Equity - Narrativ
Stockholders' Equity - Narrative (Details) - USD ($) | 12 Months Ended | |||
Feb. 14, 2024 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Equity, Class of Treasury Stock [Line Items] | ||||
Preferred stock, authorized (in shares) | 10,000,000 | 10,000,000 | ||
Par value - preferred stock (in usd per share) | $ 0.01 | $ 0.01 | ||
Preferred stock, issued (in shares) | 0 | 0 | ||
Special distribution utilized to make tax payments | $ 30,000,000 | |||
Common Class A | Subsequent Event | ||||
Equity, Class of Treasury Stock [Line Items] | ||||
Quarterly dividend, declared (in usd per share) | $ 0.4033 | |||
Common Class C | Subsequent Event | ||||
Equity, Class of Treasury Stock [Line Items] | ||||
Quarterly dividend, declared (in usd per share) | 0.4033 | |||
Common Class B | Subsequent Event | ||||
Equity, Class of Treasury Stock [Line Items] | ||||
Quarterly dividend, declared (in usd per share) | 0.4033 | |||
Common Class D | Subsequent Event | ||||
Equity, Class of Treasury Stock [Line Items] | ||||
Quarterly dividend, declared (in usd per share) | $ 0.4033 | |||
CEG | ||||
Equity, Class of Treasury Stock [Line Items] | ||||
Special distribution paid | 21,000,000 | |||
ATM Programs | ||||
Equity, Class of Treasury Stock [Line Items] | ||||
Aggregate sales price | 150,000,000 | |||
Available for issuance under ATM program | $ 126,000,000 | |||
ATM Programs | Common Class C | ||||
Equity, Class of Treasury Stock [Line Items] | ||||
Sale of stock, number of shares issued in transaction | 0 | 0 | 0 |
Stockholders' Equity - Schedule
Stockholders' Equity - Schedule of Dividends Paid (Details) - $ / shares | 3 Months Ended | 12 Months Ended | |||||
Dec. 31, 2023 | Sep. 30, 2023 | Jun. 30, 2023 | Mar. 31, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Common Class A | |||||||
Equity, Class of Treasury Stock [Line Items] | |||||||
Dividends per common share (in usd per share) | $ 0.3964 | $ 0.3891 | $ 0.3818 | $ 0.3745 | $ 1.54 | $ 1.43 | $ 1.33 |
Common Class C | |||||||
Equity, Class of Treasury Stock [Line Items] | |||||||
Dividends per common share (in usd per share) | $ 0.3964 | $ 0.3891 | $ 0.3818 | $ 0.3745 | $ 1.54 | $ 1.43 | $ 1.33 |
Stockholders' Equity - Schedu_2
Stockholders' Equity - Schedule of Distributions Paid (Details) - Clearway Energy LLC - $ / shares | 3 Months Ended | |||
Dec. 31, 2023 | Sep. 30, 2023 | Jun. 30, 2023 | Mar. 31, 2023 | |
Common Class B | ||||
Equity, Class of Treasury Stock [Line Items] | ||||
Quarterly dividend, declared (in usd per share) | $ 0.3964 | $ 0.3891 | $ 0.3818 | $ 0.3745 |
Common Class D | ||||
Equity, Class of Treasury Stock [Line Items] | ||||
Quarterly dividend, declared (in usd per share) | $ 0.3964 | $ 0.3891 | $ 0.3818 | $ 0.3745 |
Segment Reporting (Details)
Segment Reporting (Details) - USD ($) $ in Millions | 12 Months Ended | |||
May 31, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Segment Reporting | ||||
Operating revenues | $ 1,314 | $ 1,190 | $ 1,286 | |
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 473 | 435 | 451 | |
Depreciation, amortization and accretion | 526 | 512 | 509 | |
Impairment losses | 12 | 16 | 6 | |
General and administrative | 36 | 40 | 40 | |
Transaction and integration costs | 4 | 7 | 7 | |
Development costs | 0 | 2 | 6 | |
Total operating costs and expenses | 1,051 | 1,012 | 1,019 | |
Gain on sale of business | 0 | 1,292 | 0 | |
Operating income (loss) | 263 | 1,470 | 267 | |
Equity in earnings of unconsolidated affiliates | 12 | 29 | 32 | |
Other income, net | 52 | 17 | 3 | |
Loss on debt extinguishment | (6) | (2) | (53) | |
Interest expense | (337) | (232) | (312) | |
(Loss) Income Before Income Taxes | (16) | 1,282 | (63) | |
Income tax (benefit) expense | (2) | 222 | 12 | |
Net income (loss) | $ 8 | (14) | 1,060 | (75) |
Net income attributable to Clearway Energy, Inc. | 79 | 582 | 51 | |
Equity investments in affiliates | 360 | 364 | ||
Capital expenditures | 157 | 56 | ||
Total Assets | 14,701 | 12,312 | ||
Operating Segments | ||||
Segment Reporting | ||||
Operating revenues | 1,314 | 1,190 | 1,286 | |
Operating Segments | Conventional Generation | ||||
Segment Reporting | ||||
Operating revenues | 420 | 417 | 441 | |
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 154 | 89 | 90 | |
Depreciation, amortization and accretion | 129 | 131 | 132 | |
Impairment losses | 0 | 0 | 0 | |
General and administrative | 0 | 0 | 0 | |
Transaction and integration costs | 0 | 0 | 0 | |
Development costs | 0 | 0 | ||
Total operating costs and expenses | 220 | |||
Gain on sale of business | 0 | |||
Operating income (loss) | 137 | 197 | 219 | |
Equity in earnings of unconsolidated affiliates | 3 | 3 | 6 | |
Other income, net | 4 | 1 | 0 | |
Loss on debt extinguishment | 0 | 0 | 0 | |
Interest expense | (35) | (40) | (53) | |
(Loss) Income Before Income Taxes | 109 | 161 | 172 | |
Income tax (benefit) expense | 0 | 0 | 0 | |
Net income (loss) | 109 | 161 | 172 | |
Net income attributable to Clearway Energy, Inc. | 109 | 161 | 172 | |
Equity investments in affiliates | 79 | 82 | ||
Capital expenditures | 11 | 11 | ||
Total Assets | 2,058 | 2,251 | ||
Operating Segments | Renewables | ||||
Segment Reporting | ||||
Operating revenues | 894 | 696 | 641 | |
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 321 | 298 | 229 | |
Depreciation, amortization and accretion | 397 | 381 | 354 | |
Impairment losses | 12 | 16 | 6 | |
General and administrative | 0 | 0 | 0 | |
Transaction and integration costs | 0 | 0 | 0 | |
Development costs | 0 | 0 | ||
Total operating costs and expenses | 695 | |||
Gain on sale of business | 0 | |||
Operating income (loss) | 164 | 1 | 52 | |
Equity in earnings of unconsolidated affiliates | 9 | 26 | 26 | |
Other income, net | 24 | 6 | 2 | |
Loss on debt extinguishment | (6) | (2) | (1) | |
Interest expense | (205) | (87) | (142) | |
(Loss) Income Before Income Taxes | (14) | (56) | (63) | |
Income tax (benefit) expense | (2) | 2 | 2 | |
Net income (loss) | (12) | (58) | (65) | |
Net income attributable to Clearway Energy, Inc. | 150 | 49 | 109 | |
Equity investments in affiliates | 281 | 282 | ||
Capital expenditures | 146 | 33 | ||
Total Assets | 12,205 | 9,515 | ||
Operating Segments | Thermal | ||||
Segment Reporting | ||||
Operating revenues | 77 | 204 | ||
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 50 | 134 | ||
Depreciation, amortization and accretion | 0 | 23 | ||
Impairment losses | 0 | 0 | ||
General and administrative | 2 | 4 | ||
Transaction and integration costs | 0 | 0 | ||
Development costs | 2 | 4 | ||
Total operating costs and expenses | 54 | |||
Gain on sale of business | 0 | |||
Operating income (loss) | 23 | 39 | ||
Equity in earnings of unconsolidated affiliates | 0 | 0 | ||
Other income, net | 0 | 1 | ||
Loss on debt extinguishment | 0 | 0 | 0 | |
Interest expense | (6) | (18) | ||
(Loss) Income Before Income Taxes | 17 | 22 | ||
Income tax (benefit) expense | 0 | 0 | 0 | |
Net income (loss) | 17 | 22 | ||
Net income attributable to Clearway Energy, Inc. | 17 | 22 | ||
Equity investments in affiliates | 0 | |||
Capital expenditures | 11 | |||
Total Assets | 0 | |||
Corporate | ||||
Segment Reporting | ||||
Operating revenues | 0 | 0 | 0 | |
Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | (2) | (2) | (2) | |
Depreciation, amortization and accretion | 0 | 0 | 0 | |
Impairment losses | 0 | 0 | 0 | |
General and administrative | 36 | 38 | 36 | |
Transaction and integration costs | 4 | 7 | 7 | |
Development costs | 0 | 2 | ||
Total operating costs and expenses | 43 | |||
Gain on sale of business | 1,292 | |||
Operating income (loss) | (38) | 1,249 | (43) | |
Equity in earnings of unconsolidated affiliates | 0 | 0 | 0 | |
Other income, net | 24 | 10 | 0 | |
Loss on debt extinguishment | 0 | (52) | ||
Interest expense | (97) | (99) | (99) | |
(Loss) Income Before Income Taxes | (111) | 1,160 | (194) | |
Income tax (benefit) expense | 220 | 10 | ||
Net income (loss) | (111) | 940 | (204) | |
Net income attributable to Clearway Energy, Inc. | (180) | 355 | $ (252) | |
Equity investments in affiliates | 0 | 0 | ||
Capital expenditures | 0 | 1 | ||
Total Assets | $ 438 | $ 546 | ||
Southern California Edison | Conventional Generation | ||||
Segment Reporting | ||||
Customer's percentage of total revenue | 11% | 17% | 17% | |
Southern California Edison | Renewables | ||||
Segment Reporting | ||||
Customer's percentage of total revenue | 13% | 17% | 16% | |
PG&E | Conventional Generation | ||||
Segment Reporting | ||||
Customer's percentage of total revenue | 4% | 10% | 10% | |
PG&E | Renewables | ||||
Segment Reporting | ||||
Customer's percentage of total revenue | 13% | 15% | 13% | |
CALIFORNIA | Revenue Benchmark | Geographic Concentration Risk | ||||
Segment Reporting | ||||
Percentage of total operating revenue and assets | 50% |
Income Taxes - Schedule of Inco
Income Taxes - Schedule of Income Tax Provision (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Income Tax Expense (Benefit), Continuing Operations [Abstract] | |||
U.S. Federal | $ (13) | $ 0 | $ 0 |
State | (2) | 28 | 0 |
Current Income Tax Expense (Benefit) | (15) | 28 | 0 |
Deferred | |||
U.S. Federal | 13 | 150 | (2) |
State | 0 | 44 | 14 |
Total — deferred | 13 | 194 | 12 |
Total income tax (benefit) expense | $ (2) | $ 222 | $ 12 |
Income Taxes - Schedule of Reco
Income Taxes - Schedule of Reconciliation of the U.S. Federal Statutory Rate (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Tax Credit Carryforward [Line Items] | |||
(Loss) Income Before Income Taxes | $ (16) | $ 1,282 | $ (63) |
Tax at 21% | (3) | 269 | (13) |
State taxes, net of federal benefit | (2) | 58 | (4) |
Impact of non-taxable partnership earnings (losses) | 21 | (101) | 34 |
Valuation allowance | 3 | 0 | (14) |
Investment tax credits | (1) | 0 | 0 |
Production tax credits | (16) | (2) | (1) |
Rate change | 1 | (2) | (2) |
Partnership state basis | 0 | 0 | 8 |
State taxes assessed at subsidiaries | (3) | 2 | 2 |
Other | (2) | (2) | 2 |
Income tax (benefit) expense | $ (2) | $ 222 | $ 12 |
Effective income tax rate | 12.50% | 17.30% | (19.00%) |
Alta TE Holdco LLC | |||
Tax Credit Carryforward [Line Items] | |||
Income tax (benefit) expense | $ 14 |
Income Taxes - Schedule of Comp
Income Taxes - Schedule of Company's Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Deferred Tax Liabilities, Gross [Abstract] | ||
Total deferred tax assets, net of valuation allowance | $ 241 | $ 240 |
Total deferred tax liabilities | 241 | 240 |
Deferred tax assets: | ||
Interest expense disallowance carryforward - Investment in Projects | 17 | 0 |
Production tax credits | 15 | 13 |
Investment tax credits | 6 | 5 |
U.S. Federal net operating loss carryforwards | 73 | 100 |
State net operating loss carryforwards | 7 | 4 |
Total deferred tax assets | 118 | 122 |
Valuation allowance | (4) | (1) |
Total deferred tax assets, net of valuation allowance | 114 | |
Net deferred non-current tax liability | 121 | |
Total deferred tax liabilities | $ (127) | $ (119) |
Income Taxes - Narrative (Detai
Income Taxes - Narrative (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Tax Credit Carryforward [Line Items] | ||
Taxes receivable | $ 13 | |
Deferred Tax Liabilities, Net | (127) | $ (119) |
Valuation allowance | (4) | (1) |
U.S. Federal net operating loss carryforwards | 73 | 100 |
State net operating loss carryforwards | 7 | $ 4 |
Investment Tax Credit | ||
Tax Credit Carryforward [Line Items] | ||
Carryforward balance | $ 21 |
Related Party Transactions (Det
Related Party Transactions (Details) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 USD ($) subsidiary | Dec. 31, 2022 USD ($) | Dec. 31, 2021 USD ($) | |
Related Party Transaction | |||
General and administrative | $ 36 | $ 40 | $ 40 |
Affiliated Entity | Administrative Services Agreements | |||
Related Party Transaction | |||
Expenses from transactions with related party | 20 | 16 | 14 |
Due to related party | $ 2 | 3 | |
Number of wholly owned subsidiaries | subsidiary | 2 | ||
Related Party | RENOM | |||
Related Party Transaction | |||
Expenses from transactions with related party | $ 73 | 71 | 56 |
Due to related party | $ 13 | 14 | |
Related Party | CEG | |||
Related Party Transaction | |||
General and administrative | $ 5 | $ 4 |
Commitment and Contingencies (D
Commitment and Contingencies (Details) $ in Millions | 12 Months Ended | ||
Nov. 14, 2023 party | Dec. 31, 2022 USD ($) | Dec. 31, 2021 USD ($) | |
Loss Contingencies [Line Items] | |||
Power procurement arrangements | $ | $ 20 | $ 40 | |
Buckthorn Solar Litigation | Settled Litigation | |||
Loss Contingencies [Line Items] | |||
Number of parties in lawsuit | party | 2 |
Leases - Lease Cost (Details)
Leases - Lease Cost (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Leases [Abstract] | |||
Operating lease cost - Fixed | $ 40 | $ 36 | $ 27 |
Operating lease cost - Variable | 11 | 11 | 15 |
Total lease cost | 51 | 47 | $ 42 |
ASSETS | |||
Right-of-use assets, net | $ 597 | $ 527 | |
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List] | Long-term lease liability - operating leases | Long-term lease liability - operating leases | |
Liabilities [Abstract] | |||
Short-term lease liability - operating leases | $ 7 | $ 6 | |
Long-term lease liability - operating leases | 627 | 548 | |
Total lease liabilities | $ 634 | $ 554 | |
Weighted average remaining lease term (in years) | 28 years | 27 years | |
Weighted average discount rate | 4.20% | 4.10% | |
Cash paid for operating leases | $ 30 | $ 28 |
Leases - Maturities of Operatin
Leases - Maturities of Operating Lease Liabilities (Details) $ in Millions | Dec. 31, 2023 USD ($) |
Leases [Abstract] | |
2024 | $ 34 |
2025 | 34 |
2026 | 35 |
2027 | 36 |
2028 | 36 |
Thereafter | 980 |
Total lease payments | 1,155 |
Less imputed interest | (521) |
Total lease liability - operating leases | $ 634 |
Leases - Land Lease with Wholly
Leases - Land Lease with Wholly-Owned Subsidiary (Details) $ in Millions | Dec. 31, 2023 USD ($) renewalOption | May 31, 2023 | Dec. 31, 2022 USD ($) |
Lessee, Lease, Description [Line Items] | |||
Right-of-use assets, net | $ 597 | $ 527 | |
Long-term lease liabilities | 634 | ||
Renewal period | 5 years | ||
Daggett 2 | CEG | |||
Lessee, Lease, Description [Line Items] | |||
Right-of-use assets, net | 22 | ||
Long-term lease liabilities | 23 | ||
Daggett 3 | CEG | |||
Lessee, Lease, Description [Line Items] | |||
Right-of-use assets, net | 31 | ||
Long-term lease liabilities | 33 | ||
Mililani I | CEG | |||
Lessee, Lease, Description [Line Items] | |||
Right-of-use assets, net | 19 | 19 | |
Long-term lease liabilities | $ 20 | 20 | |
Oahu Solar LLC | |||
Lessee, Lease, Description [Line Items] | |||
Number of renewal options | renewalOption | 2 | ||
Renewal period | 5 years | ||
Oahu Solar LLC | CEG | |||
Lessee, Lease, Description [Line Items] | |||
Right-of-use assets, net | $ 17 | 17 | |
Long-term lease liabilities | 20 | 20 | |
Rosamond Central | CEG | |||
Lessee, Lease, Description [Line Items] | |||
Right-of-use assets, net | 11 | 11 | |
Long-term lease liabilities | $ 12 | $ 12 |
Leases - Revenue Related to Lea
Leases - Revenue Related to Leases (Details) - USD ($) $ in Millions | 12 Months Ended | |||
May 31, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Disaggregation of Revenue [Line Items] | ||||
Renewal period | 5 years | |||
Lease receivable | $ 21 | |||
Net investment costs | 13 | |||
Net (Loss) Income | $ 8 | $ (14) | $ 1,060 | $ (75) |
Energy revenue | Conventional Generation | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 4 | 6 | 9 | |
Energy revenue | Renewables | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 760 | 809 | 716 | |
Energy revenue | Thermal | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 1 | 2 | ||
Energy revenue | Total Segments | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 764 | 816 | 727 | |
Capacity revenue | Conventional Generation | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 249 | 435 | 455 | |
Capacity revenue | Renewables | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 20 | 0 | 0 | |
Capacity revenue | Thermal | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 0 | 0 | ||
Capacity revenue | Total Segments | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 269 | 435 | 455 | |
Operating revenues | Conventional Generation | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 274 | 441 | 464 | |
Operating revenues | Renewables | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 780 | 809 | 716 | |
Operating revenues | Thermal | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 1 | 2 | ||
Operating revenues | Total Segments | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 1,054 | $ 1,251 | $ 1,182 | |
Other revenue | Conventional Generation | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 21 | |||
Other revenue | Renewables | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | 0 | |||
Other revenue | Total Segments | ||||
Disaggregation of Revenue [Line Items] | ||||
Lease revenue | $ 21 |
Leases - Lessor Minimum Future
Leases - Lessor Minimum Future Rent Payments Under Operating Leases (Details) $ in Millions | Dec. 31, 2023 USD ($) |
Leases [Abstract] | |
2024 | $ 146 |
2025 | 147 |
2026 | 148 |
2027 | 149 |
2028 | 150 |
Thereafter | 1,635 |
Total lease payments | $ 2,375 |
Leases - Property, Plant and Eq
Leases - Property, Plant and Equipment Related to Operating Leases (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Leases [Abstract] | ||
Property, plant and equipment | $ 5,720 | $ 8,630 |
Accumulated depreciation | (1,991) | (2,855) |
Property, plant and equipment | $ 3,729 | $ 5,775 |
Schedule I - Condensed Financ_2
Schedule I - Condensed Financial Information of Registrant - P/L (Details) - USD ($) $ in Millions | 12 Months Ended | |||
May 31, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Condensed Financial Statements, Captions [Line Items] | ||||
Total other expense, net | $ (279) | $ (188) | $ (330) | |
(Loss) Income Before Income Taxes | (16) | 1,282 | (63) | |
Income tax (benefit) expense | (2) | 222 | 12 | |
Net (Loss) Income | $ 8 | (14) | 1,060 | (75) |
Less: Net (loss) income attributable to noncontrolling interests and redeemable noncontrolling interests | (93) | 478 | (126) | |
Clearway Energy, Inc. | ||||
Condensed Financial Statements, Captions [Line Items] | ||||
Total operating costs and expenses | 1 | 2 | 2 | |
Equity in (losses) earnings of consolidated subsidiaries | (13) | 1,282 | (63) | |
Total other expense, net | (13) | 1,282 | (63) | |
(Loss) Income Before Income Taxes | (14) | 1,280 | (65) | |
Income tax (benefit) expense | 0 | 220 | 10 | |
Net (Loss) Income | (14) | 1,060 | (75) | |
Less: Net (loss) income attributable to noncontrolling interests and redeemable noncontrolling interests | (93) | 478 | (126) | |
Net Income Attributable to Clearway Energy, Inc. | $ 79 | $ 582 | $ 51 |
Schedule I - Condensed Financ_3
Schedule I - Condensed Financial Information of Registrant - B/S (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 |
Other Assets | ||||
Total Assets | $ 14,701 | $ 12,312 | ||
Other Liabilities | ||||
Long-term debt | 8,099 | |||
Other non-current liabilities | 286 | 201 | ||
Total Liabilities | 9,706 | 8,279 | ||
Stockholders’ Equity | ||||
Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued | 0 | 0 | ||
Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 202,080,794 shares issued and outstanding (Class A 34,613,853, Class B 42,738,750, Class C 82,391,441, Class D 42,336,750) at December 31, 2023 and 201,972,813 shares issued and outstanding (Class A 34,613,853, Class B 42,738,750, Class C 82,283,460, Class D 42,336,750) at December 31, 2022 | 1 | 1 | ||
Additional paid-in capital | 1,732 | 1,761 | ||
Retained earnings | 361 | 463 | ||
Accumulated other comprehensive income | 7 | 9 | ||
Noncontrolling interest | 2,893 | 1,792 | ||
Total Stockholders’ Equity | 4,994 | 4,026 | $ 3,300 | $ 2,715 |
Total Liabilities and Stockholders’ Equity | $ 14,701 | $ 12,312 | ||
Common stock, shares authorized (in shares) | 3,000,000,000 | 3,000,000,000 | ||
Common Class A | ||||
Stockholders’ Equity | ||||
Common stock, shares authorized (in shares) | 500,000,000 | 500,000,000 | ||
Common Class B | ||||
Stockholders’ Equity | ||||
Common stock, shares authorized (in shares) | 500,000,000 | 500,000,000 | ||
Common Class C | ||||
Stockholders’ Equity | ||||
Common stock, shares authorized (in shares) | 1,000,000,000 | 1,000,000,000 | ||
Common Class D | ||||
Stockholders’ Equity | ||||
Common stock, shares authorized (in shares) | 1,000,000,000 | 1,000,000,000 | ||
Affiliated Entity | ||||
Current Assets | ||||
Note receivable — affiliate | $ 174 | $ 0 | ||
Current Liabilities | ||||
Accounts payable — affiliates | 31 | 22 | ||
Clearway Energy, Inc. | ||||
Current Assets | ||||
Note receivable — affiliate | 1 | 2 | ||
Other current assets | 13 | 0 | ||
Other Assets | ||||
Investment in consolidated subsidiaries | 5,106 | 4,161 | ||
Total Assets | 5,123 | 4,165 | ||
Current Liabilities | ||||
Accounts payable — affiliates | 0 | 19 | ||
Other Liabilities | ||||
Long-term debt | 125 | 115 | ||
Other non-current liabilities | 4 | 5 | ||
Total Liabilities | 129 | 139 | ||
Stockholders’ Equity | ||||
Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued | 0 | 0 | ||
Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 202,080,794 shares issued and outstanding (Class A 34,613,853, Class B 42,738,750, Class C 82,391,441, Class D 42,336,750) at December 31, 2023 and 201,972,813 shares issued and outstanding (Class A 34,613,853, Class B 42,738,750, Class C 82,283,460, Class D 42,336,750) at December 31, 2022 | 1 | 1 | ||
Additional paid-in capital | 1,732 | 1,761 | ||
Retained earnings | 361 | 463 | ||
Accumulated other comprehensive income | 7 | 9 | ||
Noncontrolling interest | 2,893 | 1,792 | ||
Total Stockholders’ Equity | 4,994 | 4,026 | ||
Total Liabilities and Stockholders’ Equity | $ 5,123 | $ 4,165 | ||
Common stock, shares authorized (in shares) | 3,000,000,000 | 3,000,000,000 | ||
Clearway Energy, Inc. | Common Class A | ||||
Stockholders’ Equity | ||||
Common stock, shares authorized (in shares) | 500,000,000 | 500,000,000 | ||
Clearway Energy, Inc. | Common Class B | ||||
Stockholders’ Equity | ||||
Common stock, shares authorized (in shares) | 500,000,000 | 500,000,000 | ||
Clearway Energy, Inc. | Common Class C | ||||
Stockholders’ Equity | ||||
Common stock, shares authorized (in shares) | 1,000,000,000 | 1,000,000,000 | ||
Clearway Energy, Inc. | Common Class D | ||||
Stockholders’ Equity | ||||
Common stock, shares authorized (in shares) | 1,000,000,000 | 1,000,000,000 | ||
Clearway Energy, Inc. | Affiliated Entity | ||||
Current Assets | ||||
Accounts receivable — trade | $ 3 | $ 2 |
Schedule I - Condensed Financ_4
Schedule I - Condensed Financial Information of Registrant - B/S Parenthetical (Details) - $ / shares | Dec. 31, 2023 | Dec. 31, 2022 |
Condensed Financial Statements, Captions [Line Items] | ||
Par value - preferred stock (in usd per share) | $ 0.01 | $ 0.01 |
Preferred stock, authorized (in shares) | 10,000,000 | 10,000,000 |
Preferred stock, issued (in shares) | 0 | 0 |
Common stock, shares authorized (in shares) | 3,000,000,000 | 3,000,000,000 |
Common stock, shares issued (in shares) | 202,080,794 | 201,972,813 |
Common stock, shares outstanding (in shares) | 202,080,794 | 201,972,813 |
Common Class A | ||
Condensed Financial Statements, Captions [Line Items] | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 500,000,000 | 500,000,000 |
Common stock, shares issued (in shares) | 34,613,853 | 34,613,853 |
Common stock, shares outstanding (in shares) | 34,613,853 | 34,613,853 |
Common Class B | ||
Condensed Financial Statements, Captions [Line Items] | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 500,000,000 | 500,000,000 |
Common stock, shares issued (in shares) | 42,738,750 | 42,738,750 |
Common stock, shares outstanding (in shares) | 42,738,750 | 42,738,750 |
Common Class C | ||
Condensed Financial Statements, Captions [Line Items] | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 1,000,000,000 | 1,000,000,000 |
Common stock, shares issued (in shares) | 82,391,441 | 82,283,460 |
Common stock, shares outstanding (in shares) | 82,391,441 | 82,283,460 |
Common Class D | ||
Condensed Financial Statements, Captions [Line Items] | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 1,000,000,000 | 1,000,000,000 |
Common stock, shares issued (in shares) | 42,336,750 | 42,336,750 |
Common stock, shares outstanding (in shares) | 42,336,750 | 42,336,750 |
Clearway Energy, Inc. | ||
Condensed Financial Statements, Captions [Line Items] | ||
Par value - preferred stock (in usd per share) | $ 0.01 | $ 0.01 |
Preferred stock, authorized (in shares) | 10,000,000 | 10,000,000 |
Preferred stock, issued (in shares) | 0 | 0 |
Common stock, shares authorized (in shares) | 3,000,000,000 | 3,000,000,000 |
Common stock, shares issued (in shares) | 202,080,794 | 201,972,813 |
Common stock, shares outstanding (in shares) | 202,080,794 | 201,972,813 |
Clearway Energy, Inc. | Common Class A | ||
Condensed Financial Statements, Captions [Line Items] | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 500,000,000 | 500,000,000 |
Common stock, shares issued (in shares) | 34,613,853 | 34,613,853 |
Common stock, shares outstanding (in shares) | 34,613,853 | 34,613,853 |
Clearway Energy, Inc. | Common Class B | ||
Condensed Financial Statements, Captions [Line Items] | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 500,000,000 | 500,000,000 |
Common stock, shares issued (in shares) | 42,738,750 | 42,738,750 |
Common stock, shares outstanding (in shares) | 42,738,750 | 42,738,750 |
Clearway Energy, Inc. | Common Class C | ||
Condensed Financial Statements, Captions [Line Items] | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 1,000,000,000 | 1,000,000,000 |
Common stock, shares issued (in shares) | 82,391,441 | 82,283,460 |
Common stock, shares outstanding (in shares) | 82,391,441 | 82,283,460 |
Clearway Energy, Inc. | Common Class D | ||
Condensed Financial Statements, Captions [Line Items] | ||
Par value - common stock (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 1,000,000,000 | 1,000,000,000 |
Common stock, shares issued (in shares) | 42,336,750 | 42,336,750 |
Common stock, shares outstanding (in shares) | 42,336,750 | 42,336,750 |
Schedule I - Condensed Financ_5
Schedule I - Condensed Financial Information of Registrant - CF (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Cash Flows from Operating Activities | |||
Net Cash Used in Operating Activities | $ 702 | $ 787 | $ 701 |
Cash Flows from Investing Activities | |||
Cash advances for notes receivable — affiliate | (174) | 0 | 0 |
Net Cash Provided by (Used in) Investing Activities | (523) | 1,065 | (865) |
Cash Flows from Financing Activities | |||
Net Cash Provided by Financing Activities | (124) | (1,510) | 367 |
Net Change in Cash | 55 | 342 | 189 |
Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 996 | 654 | 465 |
Cash, Cash Equivalents and Restricted Cash at End of Period | 1,051 | 996 | 654 |
Clearway Energy, Inc. | |||
Cash Flows from Operating Activities | |||
Net Cash Used in Operating Activities | (31) | (10) | (2) |
Cash Flows from Investing Activities | |||
Investments in consolidated affiliates | 0 | 0 | 2 |
Cash advances for notes receivable — affiliate | 0 | (4) | (2) |
Cash received from notes receivable — affiliate | 1 | 3 | 2 |
Net Cash Provided by (Used in) Investing Activities | 1 | (1) | 2 |
Cash Flows from Financing Activities | |||
Cash received from Clearway Energy LLC for tax-related distributions | 30 | 11 | 0 |
Cash received from Clearway Energy LLC for the payment of dividends | 180 | 167 | 155 |
Payment of dividends | (180) | (167) | (155) |
Net Cash Provided by Financing Activities | 30 | 11 | 0 |
Net Change in Cash | 0 | 0 | 0 |
Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 0 | 0 | 0 |
Cash, Cash Equivalents and Restricted Cash at End of Period | $ 0 | $ 0 | $ 0 |
Schedule I - Condensed Financ_6
Schedule I - Condensed Financial Information of Registrant - Footnotes (Details) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 USD ($) MW | Dec. 31, 2022 USD ($) | Dec. 31, 2021 USD ($) | |
Condensed Cash Flow Statements, Captions [Line Items] | |||
Power generation capacity, megawatts (over) | 8,500 | ||
Cash distributions | $ | $ 180 | $ 167 | $ 155 |
Conventional Generation, Utility-Scale Solar, Distributed Solar, and Wind | |||
Condensed Cash Flow Statements, Captions [Line Items] | |||
Power generation capacity, megawatts (over) | 6,000 | ||
Generational Facilities and District Energy Systems | |||
Condensed Cash Flow Statements, Captions [Line Items] | |||
Power generation capacity, megawatts (over) | 2,500 | ||
Clearway Energy LLC | CEG | |||
Condensed Cash Flow Statements, Captions [Line Items] | |||
Ownership interest (as a percentage) | 42.10% |
Schedule II (Details)
Schedule II (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward] | |||
Balance at beginning of period | $ 1 | $ 1 | $ 15 |
Charged to costs and expenses | 3 | 0 | (14) |
Charged to other accounts | 0 | 0 | 0 |
Balance at end of period | $ 4 | $ 1 | $ 1 |