UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-K
| | | | | | | | | | | |
| ☒ | | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
| | For the Fiscal Year ended | December 31, 2021 |
| | | 2022 |
| ☐ | | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the Transition period from to . |
Commission File Number: 333-203369
Clearway Energy LLC
(Exact name of registrant as specified in its charter) | | | | | | | | | | | |
| Delaware | | 32-0407370 |
| (State or other jurisdiction of incorporation or organization) | | (I.R.S. Employer Identification No.) |
| 300 Carnegie Center, Suite 300 | Princeton | New Jersey | 08540 |
| (Address of principal executive offices) | (Zip Code) |
(609) 608-1525
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
None
Securities registered pursuant to Section 12(g) of the Act:
None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes o No x
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act. Yes x No o
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No o
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes x No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of "large“large accelerated filer," "accelerated” “accelerated filer," "smaller” “smaller reporting company,"” and "emerging“emerging growth company"company” in Rule 12b-2 of the Exchange Act.
| | | | | | | | | | | |
| Large accelerated filer | ☐ | Accelerated filer | ☐ |
| Non-accelerated filer | ☒ | Smaller reporting company | ☐ |
| | Emerging growth company | ☐ |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes ☐ No x
Indicate by check mark whether the registrant has filed a report on and attestation to its management'smanagement’s assessment of the effectiveness of its internal control over financial reporting under section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☐
Clearway Energy LLC'sLLC’s outstanding equity interests are held by Clearway Energy, Inc. and Clearway Energy Group LLC and there are no equity interests held by non-affiliates.
Indicate the number of shares outstanding of each of the registrant'sregistrant’s classes of common stock as of the latest practicable date. There is no public market for the registrant'sregistrant’s outstanding units.
| | | | | |
| Class | Outstanding at January 31, 20222023 |
| Class A Units | 34,599,64534,613,853 |
| Class B Units | 42,738,750 |
| Class C Units | 81,764,90782,283,460 |
| Class D Units | 42,633,75042,336,750 |
Documents Incorporated by Reference:
None.
TABLE OF CONTENTS
Index | | | | | |
| GLOSSARY OF TERMS | |
| PART I | |
| Item 1 — Business | |
| Item 1A — Risk Factors | |
| Item 1B — Unresolved Staff Comments | |
| Item 2 — Properties | |
| Item 3 — Legal Proceedings | |
| Item 4 — Mine Safety Disclosures | |
| PART II | |
Item 5 — Market for Registrant'sRegistrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities | |
| Item 6 — Reserved | |
Item 7 — Management'sManagement’s Discussion and Analysis of Financial Condition and Results of Operations | |
| Item 7A — Quantitative and Qualitative Disclosures About Market Risk | |
| Item 8 — Financial Statements and Supplementary Data | |
Item 9 — Changes in and Disagreements Withwith Accountants on Accounting and Financial Disclosure | |
| Item 9A — Controls and Procedures | |
| Item 9B — Other Information | |
| PART III | |
| Item 10 — Information about Directors, Executive Officers and Corporate Governance | |
| Item 11 — Executive Compensation | |
| Item 12 — Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters | |
| Item 13 — Certain Relationships and Related Transactions, and Director Independence | |
| Item 14 — Principal Accounting Fees and Services | |
| PART IV | |
| Item 15 — Exhibits, Financial Statement Schedules | |
| EXHIBIT INDEX | |
| Item 16 — Form 10-K Summary | |
GLOSSARY OF TERMS
When the following terms and abbreviations appear in the text of this report, they have the meanings indicated below:
| | | | | | | | |
| | |
2020 Convertible Notes | | $45 million aggregate principal amount of 3.25% convertible notes due 2020, issued by Clearway Energy, Inc., which were repaid on June 1, 2020 |
2024 Senior Notes | | $500 million aggregate principal amount of 5.375% unsecured senior notes due 2024, issued by Clearway Energy Operating LLC, which were repaid on January 3,2020 |
| 2025 Senior Notes | | $600 million aggregate principal amount of 5.750%5.75% unsecured senior notes due 2025, issued by Clearway Energy Operating LLC, which were repaid in March 2021 |
| 2026 Senior Notes | | $350 million aggregate principal amount of 5.00% unsecured senior notes due 2026, issued by Clearway Energy Operating LLC, which were repaid in October 2021 |
| 2028 Senior Notes | | $850 million aggregate principal amount of 4.75% unsecured senior notes due 2028, issued by Clearway Energy Operating LLC |
| 2031 Senior Notes | | $925 million aggregate principal amount of 3.750%3.75% unsecured senior notes due 2031, issued by Clearway Energy Operating LLC |
| 2032 Senior Notes | | $350 million aggregate principal amount of 3.750%3.75% unsecured senior notes due 2032, issued by Clearway Energy Operating LLC |
| Adjusted EBITDA | | A non-GAAP measure, represents earnings before interest (including loss on debt extinguishment), tax, depreciation and amortization adjusted for mark-to-market gains or losses, asset write offs and impairments; and factors which the Company does not consider indicative of future operating performance |
| ARO | | Asset Retirement Obligation |
| | |
| ASC | | The FASB Accounting Standards Codification, which the FASB established as the source of
|
| ASU | | Accounting Standards Updates – updates to the ASC |
ATM ProgramsProgram | | At-The-Market Equity Offering Programs |
Bankruptcy Code | | Title 11 of the U.S. Code |
Bankruptcy Court | | U.S. Bankruptcy Court for the Northern District of CaliforniaProgram |
| Bridge Loan Agreement | | Senior secured bridge credit agreement entered into by Clearway Energy Operating LLC that provides a term loan facility in an aggregate principal amount of $335 million that will maturewas repaid on November 29,May 3, 2022 |
| CAFD | | A non-GAAP measure, Cash Available for Distribution is defined as of December 31, 20212022 as Adjusted EBITDA plus cash distributions/return of investment from unconsolidated affiliates, adjustments to reflect CAFD generated by unconsolidated investments that were not able to distribute project dividends prior to PG&E's emergence from bankruptcy on July 1, 2020 and subsequent release post-bankruptcy, cash receipts from notes receivable, cash distributionscontributions from noncontrolling interests, adjustments to reflect sales-type lease cash payments and payments for lease expenses, less cash distributions to noncontrolling interests, maintenance capital expenditures, pro-rata Adjusted EBITDA from unconsolidated affiliates, cash interest paid, income taxes paid, principal amortization of indebtedness, changes in prepaid and accrued capacity payments, and adjusted for development expenses.expenses |
| Capistrano Wind Portfolio | Five wind projects representing 413 MW of capacity, which includes Broken Bow and Crofton Bluffs located in Nebraska, Cedro Hill located in Texas and Mountain Wind Power I and II located in Wyoming |
| CARES Act | | The Coronavirus Aid, Relief, and Economic Security Act |
Carlsbad Drop Down | | The acquisition by the Company of the Carlsbad Energy Center, a 527 MW natural gas-fired project located in Carlsbad, CA |
| CEG | | Clearway Energy Group LLC (formerly Zephyr Renewables LLC) |
| CEG Master Services Agreement | | Master Services Agreements entered into as of August 31, 2018 and amended on February 2, 2023 between the Company, Clearway Inc.Energy LLC and Clearway Energy Operating LLC, and CEG |
| CEG ROFO Agreement | | Right of First Offer Agreement, entered into as of August 31, 2018, by and between Clearway Energy Group LLC and Clearway Energy, Inc., and solely for purposes of Section 2.4, GIP III Zephyr Acquisition Partners, L.P., as amended by the First Amendment dated February 14, 2019, the Second Amendment dated August 1, 2019, the Third Amendment dated December 6, 2019, and the Fourth Amendment dated November 2, 2020 and the Fifth Amendment dated August 2, 2021 |
| Clearway, Inc. | | Clearway Energy, Inc., the holder of the Company'sCompany’s Class A and Class C units |
| Clearway Energy Group LLC | | The holder of all of Clearway, Inc.'s’s Class B and Class D common shares and the Company'sCompany’s Class B and Class D units and, from time to time, possibly shares of Clearway, Energy, Inc.'s’s Class A and/or Class C common stock |
| | | | | | | | |
| Clearway Energy Operating LLC | | The holder of the project assets that are owned by the Company |
| COD | | Commercial Operation Date |
| Code | | Internal Revenue Code of 1986, as amended |
| Company | | Clearway Energy LLC, together with its consolidated subsidiaries |
| CVSR | | California Valley Solar Ranch |
| | | | | |
| CVSR Holdco | | CVSR Holdco LLC, the indirect owner of CVSR |
DGPV Holdco Entities | | Collectively, DGPV Holdco 1, DGPV Holdco 2 and DGPV Holdco 3 |
DGPV Holdco 1 | | DGPV Holdco 1 LLC |
| DGPV Holdco 2 | | DGPV Holdco 2 LLC |
| DGPV Holdco 3 | | DGPV Holdco 3 LLC |
Distributed Solar
| | Solar power projects, typically less than 20 MW in size (on an alternating current, or AC, basis), that primarily sell power produced to customers for usage on site, or are interconnected to sell power into the local distribution grid |
| Drop Down Assets | | Collectively, assetsAssets under common control acquired by the Company from NRG from January 1, 2014 through the period ended August 31, 2018 and from CEG from August 31, 2018 through the period ended December 31, 2021 |
ECP | | Energy Center Pittsburgh LLC, a subsidiary of the Company |
| EPA | | United States Environmental Protection Agency |
ERCOT
| | Electric Reliability Council of Texas, the ISO and the regional reliability coordinator of the various electricity systems within Texas |
| EWG | | Exempt Wholesale Generator |
| Exchange Act | | The Securities Exchange Act of 1934, as amended |
| FASB | | Financial Accounting Standards Board |
| FERC | | Federal Energy Regulatory Commission |
| FPA | | Federal Power Act |
GAAPFWS | U.S. Fish & Wildlife Service |
| GAAP | Accounting principles generally accepted in the U.S. |
| GenConn | | GenConn Energy LLC |
| GHG | | Greenhouse gas |
| GIM | | Global Infrastructure Management, LLC |
| GIP | | Global Infrastructure Partners |
| GIP Transaction | | On August 31, 2018, NRG transferred its full ownership interest in the Company to Clearway Energy Group LLC and subsequently sold 100% of its interests in Clearway Energy Group LLC, which includes NRG's renewable energy development and operations platform, to an affiliate of GIP. GIP, NRG and the Company also entered into a consent and indemnity agreement in connection with the purchase and sale agreement, which was signed on February 6, 2018 |
| HLBV | | Hypothetical Liquidation at Book Value |
IRSIRA | Inflation Reduction Act of 2022 |
| IRS | Internal Revenue Service |
| ISO | | Independent System Operator, also referred to as an RTO |
| ITC | | Investment Tax Credit |
| KKR | | KKR Thor Bidco, LLC, an affiliate of Kohlberg Kravis Roberts & Co. L.P. |
| kWh | | Kilowatt Hour |
| LIBOR | | London Inter-Bank Offered Rate |
| | |
| MBTA | | Migratory Bird Treaty Act |
| Mesquite Star | | Mesquite Star Special, LLC |
| MMBtu | | Million British Thermal Units |
| Mt. Storm | | NedPower Mount Storm LLC |
| MW | | Megawatt |
| MWh | | Saleable megawatt hours, net of internal/parasitic load megawatt-hours |
| | | | | | | | |
| MWt | | Megawatts Thermal Equivalent |
| NEPA | | National Environmental Policy Act |
| NERC | | North American Electric Reliability Corporation |
| Net Exposure | | Counterparty credit exposure to Clearway Energy LLC, net of collateral |
| |
| NOLs | Net Operating Losses |
NOx | | Nitrogen Oxides |
| NPNS | | Normal Purchases and Normal Sales |
| | | | | |
| NPPD | | Nebraska Public Power District |
| NRG | | NRG Energy, Inc. |
| OCI/OCL | | Other comprehensive income/loss |
| O&M | | Operations and Maintenance |
| PG&E | | Pacific Gas and Electric Company |
PG&E Bankruptcy | | On January 29, 2019, PG&E Corporation and Pacific Gas and Electric Company filed voluntary petitions for relief under the Bankruptcy Code in the U.S. Bankruptcy Court for the Northern District of California. On July 1, 2020 PG&E emerged from bankruptcy. |
| PJM | | PJM Interconnection, LLC |
| PPA | | Power Purchase Agreement |
| PTC | | Production Tax Credit |
| PUCT | | Public Utility Commission of Texas |
| PUHCA | | Public Utility Holding Company Act of 2005 |
| PURPA | | Public Utility Regulatory Policies Act of 1978 |
| QF | | Qualifying Facility under PURPA |
| | |
| RENOM | | Clearway Renewable Operation & Maintenance LLC |
| ROFO | | Right of First Offer |
| |
| RPS | | Renewable Portfolio Standards |
| RPV Holdco | | RPV Holdco 1 LLC |
| RTO | | Regional Transmission Organization |
| SCE | | Southern California Edison |
| SEC | | U.S. Securities and Exchange Commission |
| Senior Notes | | Collectively, the 2028 Senior Notes, the 2031 Senior Notes and the 2032 Senior Notes |
SO2 | | Sulfur Dioxide |
| SOFR | | Secured Overnight Financing Rate |
SRECSPP | Solar Power Partners |
| SREC | Solar Renewable Energy Credit |
| Tax Act | | Tax Cuts and Jobs Act of 2017 |
| Thermal Business | | The Company'sCompany’s thermal business, which consists of thermal infrastructure assets that provide steam, hot water and/or chilled water, and in some instances electricity, to commercial businesses, universities, hospitals and governmental units |
| Thermal Disposition | | On October 22, 2021, Clearway Energy Operating LLC entered into a binding agreement to sellMay 1, 2022, the Company completed the sale of 100% of its interests in the Thermal Business to KKR |
U.S.TotalEnergies | TotalEnergies SE |
| U.S. | United States of America |
| U.S. DOE | | U.S. Department of Energy |
| Utah Solar Portfolio | | Collection consistsSeven utility-scale solar farms located in Utah, representing 530 MW of Four Brothers Solar, LLC, Granite Mountain Holdings, LLC, and Iron Springs Holdings, LLC, which are equity investments owned by Four Brothers Capital, LLC, Granite Mountain Capital, LLC, and Iron Springs Capital, LLC, respectivelycapacity |
Utility Scale Solar
| | Solar power projects, typically 20 MW or greater in size (on an alternating current, or AC, basis), that are interconnected into the transmission or distribution grid to sell power at a wholesale level |
VaR | | Value at Risk |
| VIE | | Variable Interest Entity |
Wind TE Holdco | | Wind TE Holdco LLC, an 814 net MW portfolio of twelve wind projects |
PART I
Item 1 — Business
General
Clearway Energy LLC, together with its consolidated subsidiaries, or the Company, is an energy infrastructure investor with a focus on investments in clean energy and owner of modern, sustainable and long-term contracted assets across North America. The Company is sponsored by GIP and TotalEnergies through GIP’sthe portfolio company, Clearway Energy Group LLC, or CEG, which became equally owned by GIP and TotalEnergies as of September 12, 2022, when TotalEnergies acquired, through its investment in an intermediate holding company, 50% of GIP’s interest in CEG. 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.
The Company is one of the largest renewable energy owners in the U.S. with over 5,0005,500 net MW of installed wind and solar generation projects. The Company'sCompany’s over 9,0008,000 net MW of assets also includes approximately 2,500 net MW of environmentally-sound, highly efficient natural gas-fired generation facilities as well as the Thermal Business.facilities. Through this environmentally-sound, diversified and primarily contracted portfolio, the Company endeavors to increase distributions to its unit holders. The majoritySubstantially all of the Company’s generation assetsrevenues are underderived from long-term contractual arrangements for the output or capacity from these assets. The weighted average remaining contract duration of these offtake agreements was approximately 1211 years years as of December 31, 20212022 based on CAFD.
On October 22, 2021, Clearway Energy Operating LLC entered into a binding agreement to sellMay 1, 2022, the Company completed the sale of 100% of its interests in the Thermal Business to KKR Thor Bidco, LLC, an affiliate of Kohlberg Kravis Roberts & Co. L.P., or KKR, for total consideration of $1.9 billion, subject to customary closing adjustments, which is referred to herein as the Thermal Disposition. The transaction is expected to close in the first half of 2022. The Company's Thermal segment is comprised solely of the Thermal Business's results of operations.KKR. For further discussiondetails of the Thermal Disposition, refer to Item 15 — Note 3, Acquisitions and Dispositions.
As of December 31, 2021, GIP indirectly owned 42.35% of the economic interests in the Company and 54.93% of the voting interests in Clearway Energy, Inc., or Clearway, Inc.
A complete listing of the Company'sCompany’s interests in facilities, operations and/or projects owned or leased as of December 31, 20212022 can be found in Item 2 — Properties.
History
The Company was formed as a Delaware limited liability company by NRG on March 5, 2013. On August 31, 2018, NRG transferred its full ownership interest in Clearway Energy, Inc, or Clearway, Inc., and its subsidiaries to CEG, the holder of NRG’s renewable energy development and operations platform, and subsequently sold 100% of its interest in CEG to GIP. On September 12, 2022, GIP sold 50% of its interest in CEG through an intermediate holding company to TotalEnergies.
The Company is a holding company for the companies that directly and indirectly own and operate Clearway, Inc.'s’s business. As of December 31, 2021,2022, CEG, which is equally owned by GIP through CEG,and TotalEnergies, controls Clearway, Inc., and Clearway, Inc. in turn, as the sole managing member of the Company, controls the Company and its subsidiaries.
As of December 31, 2021, GIP, through2022, CEG owned 42,738,750 of each of the Company'sCompany’s Class B units and 42,336,750 of the Company’s Class D units, andwhile Clearway, Inc. owned 34,599,64534,613,853 of the Company'sCompany’s Class A units and 81,779,02182,283,460 of the Company'sCompany’s Class C units. Clearway, Inc., through its holdings of Class A units and Class C units, owned a 57.65%57.88% economic interest in the Company as of December 31, 2021.2022. Additionally, GIP, through CEG'sCEG’s holdings of Class B units and Class D units, owned a 42.35%42.12% economic interest in the Company as of December 31, 2021.2022.
The diagram below depictsrepresents a summarized structure of the Company’s organizational structureCompany as of December 31, 2021:2022:
Business Strategy
The Company'sCompany’s primary business strategy is to focus on the acquisition and ownership of assets with predictable, long-term cash flows in order that it may be able to increase the cash distributions to Clearway, Inc. over time without compromising the ongoing stability of the business.
The Company'sCompany’s plan for executing its business strategy includes the following key components:
Focus on contracted renewable energy and conventional generation. The Company owns and operates utility scale and distributed renewable energy and natural gas-fired generation assets with proven technologies, generally low operating risks and stable cash flows. The Company believes by focusing on this core asset class and leveraging its industry knowledge, it will maximize its strategic opportunities, be a leader in operational efficiency and maximize its overall financial performance. The Company also owns the Thermal Business that Clearway Energy Operating LLC has entered into a binding agreement to sell to KKR. For further discussion of the Thermal Disposition, refer to Item 15 — Note 3, Acquisitions and Dispositions.
Growing the business through acquisitions of contracted operating assets. The Company believes that its base of operations provides a platform for strategic growth through cash accretive and tax advantaged acquisitions complementary to its existing portfolio. In addition to acquiring generation facilities from third parties where the Company believes its knowledge of the market and operating expertise provides it with a competitive advantage, the Company may consummate future acquisitions from CEG. The Company believes that CEG'sCEG’s project development expertise provides the Company access to a development platform with an extensive pipeline of potential renewable energy and storage projects that are aligned to support the Company'sCompany’s growth. Furthermore, the Company has entered into the CEG ROFO Agreement, whereby CEG has granted the Company and its affiliates a right of first offer on any proposed sale, transfer or other disposition of certain assets of CEG, or the CEG ROFO Assets, until August 31, 2023. CEG is not obligated to sell the remaining CEG ROFO Assets to the Company and, if offered by CEG, the Company cannot be sure whether these assets will be offered on acceptable terms, or that the Company will choose to consummate such acquisitions. The Company and CEG work collaboratively in considering new assets to be added under the CEG ROFO Agreement or to be acquired by the Company outside of the CEG ROFO Agreement.Company. The assets listed below, all of which are included in a co-investment partnership with Hannon Armstrong Sustainable Infrastructure Capital, Inc.,partnerships, represent the Company'sCompany’s currently committed investments in projects with CEG and the CEG ROFO Assets:CEG:
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| Asset | | Technology | | Gross Capacity (MW) | | State | | COD | | Status |
Mililani IDaggett Solar 3 | | SolarSolar/Storage | | 39300 | | HICA | | 2H22 | | Committed |
Waiawa | | Solar | | 36 | | HI | | 2H221H23 | | Committed |
Daggett Solar 2 and 3 | | SolarSolar/Storage | | 482182 | | CA | | 2H22/1H232H23 | | Committed |
| Arica | | Solar/Storage | | 263 | | CA | | 2H23 | | Committed |
| Victory Pass | | Solar/Storage | | 200 | | CA | | 2H23 | | Committed |
Primary focus on North America. The Company intends to primarily focus its investments in North America (including the unincorporated territories of the U.S.).America. The Company believes that industry fundamentals in North America present it with significant opportunity to grow its portfolio without creating significant exposure to currency and sovereign risk. By primarily focusing its efforts on North America, the Company believes it will best leverage its regional knowledge of power markets, industry relationships and skill sets to maximize the performance of the Company.
Maintain sound financial practices to grow the distributions. The Company intends to maintain a commitment to disciplined financial analysis and a balanced capital structure to enable it to increase its distributions over time and serve the long-term interests of its unit holders. The Company'sCompany’s financial practices include a risk and credit policy focused on transacting with creditworthy counterparties; a financing policy, which focuses on seeking an optimal capital structure through various capital formation alternatives to minimize interest rate and refinancing risks, ensure stable distributions and maximize value. The Company intends to evaluate various alternatives for financing future acquisitions and refinancing of existing project-level debt, in each case, to reduce the cost of debt, extend maturities and maximize CAFD.
Competition
Power generation is a capital-intensive business with numerous and diverse industry participants. The Company competes on the basis of the location of its plants and on the basis of contract price and terms of individual projects. Within the power industry, there is a wide variation in terms of the capabilities, resources, nature and identity of the companies with whom the Company competes depending on the market. Competitors for energy supply are utilities, independent power producers and other providers of distributed generation. The Company also competes to acquire new projects with renewable developers who retain renewable power plant ownership, independent power producers, financial investors and other growth-oriented companies. Competitive conditions may be substantially affected by capital market conditions and by various forms of energy legislation and regulation considered by federal, state and local legislatures and administrative agencies, including tax policy. Such laws and regulations may substantially increase the costs of acquiring, constructing and operating projects, and it could be difficult for the Company to adapt to and operate under such laws and regulations.
The Company's Thermal Business has certain cost efficiencies that may form barriers to entry. Generally, there is only one district energy system in a given territory, for which the only competition comes from on-site systems. While the district energy system can usually make an effective case for the efficiency of its services, some building owners nonetheless may opt for on-site systems, either due to corporate policies regarding allocation of capital, unique situations where an on-site system might in fact prove more efficient or because of previously committed capital in systems that are already on-site. Growth in existing district energy systems generally comes from new building construction or existing building conversions within the service territory of the district energy provider. On October 22, 2021, Clearway Energy Operating LLC entered into a binding agreement to sell the Thermal Business to KKR. For further discussion of the Thermal Disposition, refer to Item 15 — Note 3, Acquisitions and Dispositions.
Competitive Strengths
Stable, high quality cash flows. The Company'sCompany’s facilities have a stable, predictable cash flow profile consisting of predominantly long-life electric generation assets that primarily sell electricity under long-term fixed priced contracts or pursuant to regulated rates with investment-grade and certain other creditworthy counterparties. The Company'smajority of the Company’s facilities have minimal fuel risk. For the Company'sCompany’s conventional assets currently contracted conventional assets,under tolling agreements, fuel is provided by the toll counterparty or the cost thereof is a pass-through cost under the Contract for Differences. When the tolling agreements expire, the conventional assets will need to procure their own fuel. The Renewable facilities have no fuel costs, and most of the Company's thermal infrastructure assets have contractual or regulatory tariff mechanisms for fuel cost recovery.costs. The offtake agreements for the Company'sCompany’s conventional and renewable generation facilities have a weighted-average remaining duration, based on CAFD, of approximately 1211 years as of December 31, 2021,2022, providing long-term cash flow stability. The Company'sCompany’s generation offtake agreements with counterparties for whom credit ratings are available have a weighted-average Moody’s rating of Ba1 based on rated capacity under contract and continues to be influenced by the PG&E Bankruptcy.contract. All of the Company'sCompany’s assets are in the U.S. and accordingly have no currency or repatriation risks.
Environmentally well-positioned portfolio of assets. The Company'sCompany’s portfolio of electric generation assets consists of over 5,0005,500 net MW of renewable generation capacity that are non-emitting sources of power generation. Additionally, the Company'sCompany’s California conventional assets consist of efficient gas generation facilities that support electric system reliability. The Company does not anticipate having to expend any significant capital expenditures in the foreseeable future to comply with current environmental regulations applicable to its generation assets. Taken as a whole, the Company believes its strategy will be a net beneficiary of current and potential environmental legislation and regulatory requirements that may serve as a catalyst for capacity retirements and improve market opportunities for environmentally well-positioned assets like the Company'sCompany’s assets once its current offtake agreements expire.
High quality, long-lived assets with low operating and capital requirements. The Company benefits from a portfolio of relatively younger assets, other than thermal infrastructure assets. The Company'sCompany’s assets are largely comprised of proven and reliable technologies, provided by leading original solar and wind equipment manufacturers such as General Electric, Siemens AG, SunPower Corporation, or SunPower, First Solar Inc., or First Solar, Vestas, Mitsubishi, Trina Solar, JA Solar and Siemens Gamesa. Given the modern nature of the portfolio, which includes a substantial number of relatively low operating and maintenance cost solar and wind generation assets, the Company expects to achieve high fleet availability and expend modest maintenance-related capital expenditures.
Significant scale and diversity. The Company is one of the largest renewable energy owners in the U.S. with over 5,0005,500 net MW of installed wind and solar generation projects. The Company'sCompany’s over 9,0008,000 net MW of assets also includes approximately 2,500 net MW of environmentally-sound, highly efficient natural gas-fired generation facilities as well as the Thermal Business.facilities. The Company'sCompany’s contracted renewable and conventional generation assets benefit from significant diversification in terms of technology, fuel type, counterparty and geography. The Company's Thermal Business consists of fifteen operations, seven of which are district energy centers that provide steam and chilled water to approximately 685 customers, and eight of which provide generation. The Company believes its scale and access to best practices across the fleet improves its business development opportunities through enhanced industry relationships, reputation and understanding of regional power market dynamics. Furthermore, the Company'sCompany’s diversification reduces its operating risk profile and reliance on any single market.
Relationship with GIP, TotalEnergies and CEG. The Company believes that its relationship with GIP, TotalEnergies and CEG provides significant benefits. Global Infrastructure Management, LLC, or GIM, the manager of GIP, is an independent infrastructure fund manager that makes equity and debt investments in infrastructure assets and businesses in both the Organization for Economic Co-operation and Development (OECD) and select emerging market countries. GIM has a strong track record of investment and value creation in the renewable energy sector. GIM also has extensive experience with publicly traded yield vehicles and development platforms, ranging from Europe'sEurope’s first application of a yield company/development company model to the largest renewable platform in Asia-Pacific. TotalEnergies is a global multi-energy company that produces and markets energies in more than 130 countries. Additionally, the Company believes that CEG provides the Company access to a highly capable renewable development and operations platform that is aligned to support the Company'sCompany’s growth.
Thermal infrastructure business has high entry costs. Significant capital has been invested to construct the Company's thermal infrastructure assets, serving as a barrier to entry in the markets in which such assets operate. The Company's thermal district energy centers are located in urban city areas, with the chilled water and steam delivery systems located underground. Constructing underground delivery systems in urban areas requires long lead times for permitting, rights of way and inspections and is costly. By contrast, the incremental cost to add new customers in existing markets is relatively low. Once thermal infrastructure is established, the Company believes it has the ability to retain customers over long periods of time and to compete effectively for additional business against stand-alone on-site heating and cooling generation facilities. Installation of stand-alone equipment can require significant modification to a building as well as significant space for equipment and funding for capital expenditures. The Company's system technologies often provide economies of scale in terms of fuel procurement, ability to switch between multiple types of fuel to generate thermal energy, and fuel conversion efficiency. On October 22, 2021, Clearway Energy Operating LLC entered into a binding agreement to sell the Thermal Business to KKR. For further discussion of the Thermal Disposition, refer to Item 15 — Note 3, Acquisitions and Dispositions.
Segment Review
The following tables summarize the Company'sCompany’s operating revenues, net income (loss) and assets by segment for the years ended December 31, 2022, 2021 2020 and 2019,2020, as discussed in Item 15 — Note 13, Segment Reporting.
| | | Year ended December 31, 2021 | | Year ended December 31, 2022 |
| (In millions) | (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate | | Total | (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate | | Total |
| Operating revenues | Operating revenues | $ | 441 | | | $ | 641 | | | $ | 204 | | | $ | — | | | $ | 1,286 | | Operating revenues | $ | 417 | | | $ | 696 | | | $ | 77 | | | $ | — | | | $ | 1,190 | |
| Net income (loss) | Net income (loss) | 172 | | | (65) | | | 22 | | | (192) | | | (63) | | Net income (loss) | 161 | | | (58) | | | 17 | | | 1,162 | | | 1,282 | |
| Total assets | Total assets | $ | 2,442 | | | $ | 9,603 | | | $ | 631 | | | $ | 42 | | | 12,718 | | Total assets | 2,251 | | | 9,515 | | | — | | | 546 | | | 12,312 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Year ended December 31, 2020 |
| (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate | | Total |
| Operating revenues | $ | 437 | | | $ | 569 | | | $ | 193 | | | $ | — | | | $ | 1,199 | |
| | | | | | | | | |
| Net income (loss) | 140 | | | (108) | | | 3 | | | (87) | | | (52) | |
| Total assets | $ | 2,575 | | | $ | 7,157 | | | $ | 627 | | | $ | 129 | | | 10,488 | |
| | | Year ended December 31, 2019 | | Year ended December 31, 2021 |
| (In millions) | (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate | | Total | (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate | | Total |
| Operating revenues | Operating revenues | $ | 346 | | | $ | 485 | | | $ | 201 | | | $ | — | | | $ | 1,032 | | Operating revenues | $ | 441 | | | $ | 641 | | | $ | 204 | | | $ | — | | | $ | 1,286 | |
| | Net income (loss) | Net income (loss) | 135 | | | (104) | | | (5) | | | (127) | | | (101) | | Net income (loss) | 172 | | | (65) | | | 22 | | | (192) | | | (63) | |
| Total assets | | Total assets | 2,442 | | | 9,603 | | | 631 | | | 42 | | | 12,718 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Year ended December 31, 2020 |
| (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate | | Total |
| Operating revenues | $ | 437 | | | $ | 569 | | | $ | 193 | | | $ | — | | | $ | 1,199 | |
| | | | | | | | | |
| Net income (loss) | 140 | | | (108) | | | 3 | | | (87) | | | (52) | |
Policy Incentives
Policy incentives in the U.S. have the effect of making the development of renewable energy projects more competitive by providing tax credits or grants and accelerated depreciation for a portion of the development costs, decreasing the costs and risks associated with developing such projects or creating demand for renewable energy assets through RPS programs. The elimination of, loss of or reduction in such incentives could decrease the attractiveness of renewable generation projects to developers, including, but not limited to, CEG, which could reduce the Company's acquisition opportunities. Such an elimination, loss or reduction could also reduce the Company's willingness to pursue or develop certain renewable energy projects due to higher operating costs or decreased revenues under its PPAs.
U.S. federal, state and local governments have established various policy incentives to support the development, financing, ownership and operation of renewable energy projects. These incentives include PTCs, ITCs, accelerated tax depreciation, PTCs, ITCs, cash grants, tax abatements and RPS programs. programs which have the effect of decreasing the costs and risks associated with developing and operating such projects or creating demand for renewable energy assets. In particular,
•Owners of wind facilities are eligible to claim the PTC, or an ITC in lieu of the PTC, provided that certain requirements are met. Similarly, owners of solar facilities are eligible to claim the ITC or, for facilities placed in service after August 16, 2022, the PTC, or an ITC in lieu of the PTC, provided certain requirements are met. Additionally, owners of energy storage facilities are eligible to claim the ITC for facilities placed in service after December 31, 2022, provided certain requirements are met. The PTC is an annual credit that is based on the amount of electricity sold by the facility during the first ten years after the facility is first placed in service. The ITC is a one-time credit that is based on a percentage of the cost of the facility and is claimed for the tax year in which the facility is first placed in service. Depending on the type of taxpayer, the PTC or ITC may be sold to an unrelated third party for cash, or in certain cases, direct payment from the government may be received. In order to qualify for the full amount of these credits in the case of facilities whose construction begins on or after January 29, 2023, certain prevailing wage and apprenticeship requirements generally must be satisfied, the details of which have been released only in part with additional details expected in future guidance. For facilities that begin construction after December 31, 2024, the PTC and ITC will no longer apply and such facilities may instead be eligible for the clean electricity production credit or clean electricity investment credit, respectively. In order to qualify for these new credits, the facility’s greenhouse gas emissions cannot be greater than zero.
•Pursuant to the U.S. federal Modified Accelerated Cost Recovery System, or MACRS, wind and solar projects are generally fully depreciateddepreciable for tax purposes over a five-year period (before taking into account certain conventions) even though the useful life of such projects is generally much longer than five years. The Tax Cuts and Jobs Act of 2017, or the Tax Act also provides the ability for windimmediate and solar projects to claim immediate100% expensing and deductibility for eligible property acquired and placed in service after September 27, 2017, and before January 1, 2023.
Owners of utility-scale wind facilities are eligible to claim an income tax credit (the PTC, or an ITC in lieu of the PTC) upon initially achieving commercial operation. The PTC is determined based on the amount of electricity produced by the wind facility during the first ten years of commercial operation. This incentive was created under the Energy Policy Act of 19922023, with phase downs permitting 80%, 60%, 40% and has been extended several times. Alternatively, an ITC equal to a percentage of the cost of a wind facility may be claimed in lieu of the PTC. In order to qualify20% expensing and deductibility for the PTC (or ITC in lieu of the PTC), construction of a wind facility must begin before a specified dateproperty acquired and the taxpayer must maintain a continuous program of construction or continuous efforts to advance the project to completion. The Internal Revenue Service, or IRS, issued guidance stating that the safe harbor for continuous efforts and continuous construction requirements will generally be satisfied if the facility is placed in service no more than four years after the year in which construction of the facility began. In response to the COVID-19 pandemic, the IRS extended this safe harbor by one year for facilities that began construction in 2016 or 2017. In 2021, the IRS further extended the continuity safe harbor period to six years for facilities that began construction in 2016 through 2019. For facilities that began construction in 2020, the continuity safe harbor was extended to five years.
Owners of solar projects are eligible to claim an ITC for new solar projects. This incentive was created under the Energy Policy Act of 2005during 2023, 2024, 2025 and has also been extended several times, including most recently by the Consolidated Appropriations Act of 2020.
Tax credits for qualifying wind and solar projects are subject to the following phase-down schedule:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Year construction of project begins | | | | | | | | | |
| 2015 | | 2016 | | 2017 | | 2018 | | 2019 | | 2020 | | 2021 | | 2022 | | 2023 | | 2024 | | | | | | | | |
PTC (a) | 100 | % | | 100 | % | | 80 | % | | 60 | % | | 40 | % | | 60 | % | | 60 | % | | — | % | | — | % | | — | % | | | | | | | | |
On Shore Wind ITC (b) | 30 | % | | 30 | % | | 24 | % | | 18 | % | | 12 | % | | 18 | % | | 18 | % | | — | % | | — | % | | — | % | | | | | | | | |
Solar ITC (c) | 30 | % | | 30 | % | | 30 | % | | 30 | % | | 30 | % | | 26 | % | | 26 | % | | 26 | % | | 22 | % | | 10 | % | | | | | | | | | |
(a) Percentage of the full PTC available for wind projects that begin construction during the applicable year.2026, respectively.
(b)• The Taxpayer Certainty and Disaster Tax Relief Act of 2020 provides for a new 30% ITC for offshore wind projects that begin construction before January 1, 2026.
(c) ITC is limited to 10% for projects not placed in service before January 1, 2026.
RPS programs, currently in place in certain states and territories, require electricity providers in the state or territory to meet a certain percentage of their retail sales with energy from renewable sources. Additionally, other states in the U.S. have set renewable energy goals to reduce GHG emissions from historic levels. The Company believes that these standards and goals will create incremental demand for renewable energy in the future.
The elimination of, loss of, or reduction in, the incentives discussed above could decrease the attractiveness of renewable energy projects to developers, including, but not limited to, CEG, which could reduce the Company's acquisition or development opportunities. Such an elimination, loss or reduction could also reduce the Company’s willingness to pursue or develop certain renewable energy projects due to higher operating costs or decreased revenues under its PPAs.
Regulatory Matters
As owners of power plants and participants in wholesale and thermal energy markets, certain of the Company'sCompany’s subsidiaries are subject to regulation by various federal and state government agencies. These agencies include FERC and the PUCT, as well as other public utility commissions in certain states where the Company'sCompany’s assets are located. Each of the Company'sCompany’s U.S. generating facilities qualifies as an EWG or QF. In addition, the Company is subject to the market rules, procedures and protocols of the various ISO and RTO markets in which it participates. Likewise, certain of the Company'sCompany’s subsidiaries must also comply with the mandatory reliability requirements imposed by NERC and the regional reliability entities in the regions where the Company has generating facilities subject to NERC'sNERC’s reliability authority. The Company'sCompany’s operations within the ERCOT footprint are not subject to rate regulation by FERC, as they are deemed to operate solely within the ERCOT market and not in interstate commerce. These operations are subject to regulation by PUCT.
FERC
FERC, among other things, regulates the transmission and the wholesale sale of electricity in interstate commerce under the authority of the FPA. The transmission and sale of electric energy occurring wholly within ERCOT is not subject to FERC’s jurisdiction. Under existing regulations, FERC has the authority to determine whether an entity owning a generation facility is an EWG, as defined in the PUHCA. FERC also has the authority to determine whether a generation facility meets the applicable criteria of a QF under the PURPA. Each of the Company’s U.S. generating facilities qualifies as either an EWG or QF.
The FPA gives FERC exclusive rate-making jurisdiction over the wholesale sale of electricity and transmission of electricity in interstate commerce of public utilities (as defined by the FPA). Under the FPA, FERC, with certain exceptions, regulates owners and operators of facilities used for the wholesale sale of electricity or transmission in interstate commerce as public utilities, and is charged with ensuring that market rules that are just and reasonable.
Public utilities are required to obtain FERC’s acceptance, pursuant to Section 205 of the FPA, of their rate schedules for the wholesale sale of electricity. Several of the Company'sCompany’s QF generating facilities and all of the Company’s non-QF generating facilities located in the U.S. outside of ERCOT make sales of electricity pursuant to market-based rates, as opposed to traditional cost-of-service regulated rates. FERC conducts a review of the market-based rates of Company public utilities and potential market power every three years according to a regional schedule established by FERC.
In accordance with the Energy Policy Act of 2005, FERC has approved the NERC as the national Energy Reliability Organization, or ERO. As the ERO, NERC is responsible for the development and enforcement of mandatory reliability standards for the wholesale electric power system, with such authority delegated in part to regional reliability entities charged with enforcement of mandatory reliability standards for the region which they are responsible for overseeing.
The PURPA was passed in 1978 in large part to promote increased energy efficiency and development of independent power producers. The PURPA created QFs to further both goals, and FERC is primarily charged with administering the PURPA as it applies to QFs. QFs are exempt from certain regulations under the FPA.
The PUHCA provides FERC with certain authority over and access to books and records of public utility holding companies not otherwise exempt by virtue of their ownership of EWGs QFs, and Foreign Utility Companies.QFs. The Company is exempt from many of the accounting, record retention, and reporting requirements of the PUHCA.
Environmental Matters
The Company is subject to a wide range of environmental laws during the development, construction, ownership and operation of facilities. These existing and future laws generally require that governmental permits and approvals be obtained before construction and maintained during operation of facilities. The Company is obligated to comply with all environmental laws and regulations applicable within each jurisdiction and required to implement environmental programs and procedures to monitor and control risks associated with the construction, operation and decommissioning of regulated or permitted energy assets. Federal and state environmental laws have historically become more stringent over time, although this trend could change in the future.
A number of regulations that may affect the Company are under review for potential revision or rescission in 2022, including the federal Migratory Bird Treaty Act (MBTA) incidental take permit regulations and federal Bald and Golden Eagle Protection Act incidental take permit regulations. Government leaders have also considered proposed MBTA legislation (Lowenthal Bill).2023. The Company will evaluate the impact of the legislation and regulations as they are revised but cannot fully predict the impact of each until anticipated revisions and legal challenges are resolved.To the extent that proposed legislation and new or revised regulations restrict or otherwise impact the Company'sCompany’s operations, the proposed legislation and regulations could have a negative impact on the Company'sCompany’s financial performance.
Proposed Federal MBTA Incidental Take Legislation and Regulations— On October 4, 2021, U.S. Fish and Wildlife Service (FWS) issued the final MBTA rule, effective December 3, 2021, restoring the MBTA to prohibit the incidental take of migratory birds. In 2021, FWS also issued an advance notice of proposed rulemaking (ANPR) advising that it intends to gather information necessary to develop proposed regulations to authorize the incidental take of migratory birds under prescribed conditions and prepare a draft environmental review pursuant to the National Environmental Policy Act. In the ANPR,Throughout 2022, FWS is considering authorizing incidental take using three primary mechanisms: exceptions to the MBTA’s prohibition on incidental take, general permits for certain activity types and specific or individual permits. FWS is seekingsought comments on when and how it should apply these three mechanisms to different typesthe content of activities.the proposed rule. The Company is workingworked with renewable industry groups to provide comments on the proposed rule. Scoping comments on the ANPR were due to FWS by December 3, 2021 and the company participated in this process through the industry groups.rule development. FWS is expectingcurrently considering how to havedraft the Draft Environmental Impact Statement out for public review duringrule and expects to issue the summer 2022 and the Final Environmental Impact Statement and Record of Decision are anticipated for the following summer 2023.
Changes to the National Environmental Policy Act — On October 7, 2021, the Council on Environmental Quality (CEQ) published notice of proposed rulemaking that would alter regulations for implementing the National Environmental Policy Act (NEPA)early in order "to generally restore regulatory provisions that were in effect for decades before being modified in 2020." Specifically, the proposed rule would (1) grant federal agencies greater discretion in developing project alternatives; (2) allow federal agencies to adopt NEPA regulations more stringent than CEQ’s regulations; and (3) require agencies to consider direct, indirect, and cumulative effects of major federal actions. The Notice represents "Phase 1" of the Biden Administration’s plans to revise NEPA regulations, which focuses on provisions that pose significant near-term interpretation or implementation challenges and that "make sense to revert to the 1978 regulatory approach."A "Phase 2" proposal that will "more broadly revisit the 2020 NEPA Regulations" is expected to be released in 2022.2023.
Proposed Federal Eagle Incidental Take Permit Proposed Rule — On September 14, 2021, the30, 2022, FWS published in the Federal Register a Notice of Proposed Rulemaking (ANPR) seeking public and regulated-community input on potential approaches for further expediting and simplifyingdraft rule revising the permit process authorizing incidental take of eagles. This advance notice of proposed rulemaking seeks comment on several approaches that could potentially underpin a more streamlined eagle incidental-take-permitting framework that was first established in 2009. Specifically, FWS is interested in comments clarifying specific aspects of the current permitting process that hinder permit application, processing, or implementation. FWS is also seeking recommendations for additional guidance that would reduce the time and/or cost associated with applying for and implementing long-term, eagle incidental take permits under existing regulations. FWS is looking for recommendations for targeted revisions that could be made to existing regulations consistentpermit program. Comments on the revised rule were due by the end of November 2022, but a 30-day extension was issued with the overall permitting framework that would reduce the time and/or cost associated with applying for and processing long-term permits for incidental take of eagles. Finally, FWS is interested infinal comments regarding potential new regulatory approaches to authorizing incidental take under the Eagle Act, particularly for projects that can be shown in advance to have minimal impacts on eagles, that would reduce the time and/or cost associated with applying for and operating under long-term permits for the incidental take of eagles.due by December 30, 2022. The Company is workingworked with renewable industry groups to provide comments on the proposed rule. Comments onrule in advance of the ANPR were duecut-off date. FWS is currently reviewing comments and it is not clear how the comments will be incorporated into the final rule or how FWS will structure the revisions to FWS by October 29, 2021 and the company participated in this process through the industry groups.eagle incidental take permit program.
Local California Air District Rules — Air districts have proposed updates to its respective rules to amend, as applicable, Best Available Control Technology criteria for stationary emissions sources including gas turbines, Toxic Air Contaminant Health Risk reporting and general reporting requirements. Rulemaking in the Los Angeles Air Basin, as regulated by South Coast Air Quality Management District, or SCAQMD, continues to update command-and-control regulations that limit NOx emissions for stationary sources in preparation for sunsetting SCAQMD’s Regional Clean Air Market, or RECLAIM, NOx cap and trade program in the next few years. The Company’s conventional generation plants meet the district’s existing and proposed amendments to command-and-control regulations. Proposed updates to local California Air District Rules are not expected to affect the operations nor compliance of the Company’s conventional generation plants.
Customers
The Company sells its electricity and environmental attributes, including RECs, primarily to local utilities under contractual arrangements. During the year ended December 31, 2021,2022, the Company derived approximately 33% of its consolidated revenue from Southern California Edison, or SCE, and approximately 23%25% of its consolidated revenue from PG&E.
Human Capital
As of December 31, 2021,2022, the Company had 304 employees, 62 of which are in Corporate and 242 of which are in the Thermal Business, which is the subject of a binding agreement to be sold to KKR. For further discussion of the Thermal Disposition, refer to Item 15 — Note 3, Acquisitions and Dispositions.58 employees. The Company also depends upon personnel of CEG for the provision of asset management, administration and O&M services.
The Company focuses on attracting, developing and retaining a team of highly talented and motivated employees. The Company regularly conducts assessments of its compensation and benefit practices and pay levels to help ensure that staff members are compensated fairlyequitably and competitively. The Company devotes extensive resources to staff development and training, including tuition assistance for career-enhancing academic and professional programs. Employee performance is measured in part based on goals that are aligned with the Company'sCompany’s annual objectives. The Company recognizes that its success is based on the talents and dedication of those it employs, and the Company is highly invested in their success. See "Environmental, Social and Governance (ESG)" below for a discussion of the Company's commitment to the health and safety of the Company's employees.
The Company is committed to maintaining a workplace that acknowledges, encourages, and values diversity and inclusion.inclusion and provides its employees with unconscious bias training. The Company believes that individual differences, experiences, and strengths enrich the culture and fabric of its organization. Having employees with backgrounds and orientations that reflect a variety of viewpoints and experiences also helps the Company to better understand the needs of its customers and the communities in which it operates.
By leveraging the multitude of backgrounds and perspectives of its team and developing ongoing relationships with diverse vendors, the Company achieves a collective strength that enhances the workplace and makes the Company a better business partner forto its customers and others with a stake in the Company’s success.
In 2020, theThe Company launched itsalso has an Equity, Partnership & Inclusion Council, or EPIC. As part of its commitment, the Company provides education on topics related to diversity, inclusion and anti-racism.equity. The Company also identified three areas of focus: Our People, Our Product & Customers and Our Purchasing. With the involvement of its employees, EPIC is advancing efforts in each of these areas to identify and implement opportunities for the Company to address equity, partnership and inclusion issues in its business activities.
Our People focuses on education and training; diversity, equity and inclusion policies and recruitment strategies; community and industry partnerships; and maintaining high employee engagement and retention.
Our Product & Customers focuses on pursuing opportunities that provide more equitable access to renewable energy for low-to-moderate income customers; supporting the diversity, equity and inclusion goals of the Company'sCompany’s offtakers; and meaningfully representing that work in the external market.
Our Purchasing focuses on establishing a non-discriminatory practices standard for the Company’s suppliers, diverse vendor sourcing and benchmarking.
In addition to the personnel of CEG, the Company relies on other third-party service providers in the daily operations of its conventional facilities and certain renewable facilities.
Environmental, Social and Governance (ESG)
The Company is committed to engaging with its stakeholders on environmental, social and governance, or ESG, matters in a proactive, holistic and integrated manner. The Company strives to provide recent, credible and comparable data to ESG agencies while engaging institutional investors and investor advocacy organizations around ESG issues. The Company'sCompany’s Corporate Governance, Conflicts and Nominating Committee reviews developing trends and emerging ESG matters as well as the Company’s strategies, activities, policies and communications regarding ESG matters, and makes recommendations to the Company'sCompany’s Board of Directors regarding potential actions by the Company.
Since December 2019,Aligned with the Company’s strategy of owning and acquiring environmentally-sound power generation assets, the Company has issued $2.1 billion of corporate green bonds under a green bond framework that applies the net proceeds to finance or refinance, in part or in full, new and existing projects and assets meeting certain criteria focused on the supply of energy from renewable resources, including solar energy and wind energy. The Company'sCompany’s projects and alignment of its Green Bond Principles (2018) are reviewed by Sustainalytics, an outside consultant with recognized expertise in ESG research and analysis.
The Company includes safety performance goals in the annual incentive plan for its management and the Company had zero fatalities in 2021. In response to the ongoing coronavirus (COVID-19) pandemic, the Company has implemented preventative measures and developed corporate and regional response plans to protect the health and safety of its employees, customers and other business counterparties, while supporting the Company’s suppliers and customers’ operations to the best of its ability in the circumstances. The Company also has modified certain business practices (including limiting non-essential business travel, implementing a temporary work-from-home policy for employees who can execute their work remotely and encouraging employees to adhere to local and regional social distancing, more stringent hygiene and cleaning protocols across the Company’s facilities and operations and self-quarantining recommendations) to support efforts to reduce the spread of COVID-19 and its variants and to conform to government restrictions and best practices encouraged by governmental and regulatory authorities. The Company continues to evaluate these measures, response plans and business practices in light of the evolving effects of COVID-19 and its variants.
As discussed in greater detail above, the Company has focused its diversity, equity and inclusion efforts in three areas: Our People, Our Product & Customers and Our Purchasing – through its launch of EPIC. With the involvement of the Company’s employees, EPIC is advancing efforts in each of these areas to identify and implement opportunities for the Company to address equity, partnership and inclusion issues in its business activities.
Available Information
The Company'sCompany’s annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports filed or furnished pursuant to section 13(a) or 15(d) of the Exchange Act are available free of charge through the SEC'sSEC’s website, www.sec.gov, and through the "Investor Relations"“Investor Relations” section of Clearway, Inc.'s’s website, www.clearwayenergy.com, as soon as reasonably practicable after they are electronically filed with, or furnished to, the SEC. The Company also routinely posts press releases, presentations, webcasts, and other information regarding the Company on Clearway, Inc.'s’s website. The information posted on Clearway, Inc.'s’s website is not a part of this report.
Item 1A — Risk Factors
Summary of Risk Factors
The Company’s business is subject to numerous risks and uncertainties, discussed in more detail in the following section. These risks include among others, the following key risks:
Risks Related to the Company’s Business
•The ongoing coronavirus (COVID-19) pandemic or any other pandemic could adversely affect the Company’s business, financial condition and results of operations.
•Certain facilities are newly constructed and may not perform as expected.
•The Company's ability to grow and make acquisitions through cash on hand is limited.
•The Company may be unable to close the Thermal Disposition.
•The Company may not be able to effectively identify or consummate any future acquisitions on favorable terms, or at all, and future acquisitions may not be accretive as a result of incorrect assumptions in the Company’s evaluation of such acquisitions, unforeseen consequences or other external events beyond the Company’s control.
•Counterparties to the Company'sCompany’s offtake agreements may not fulfill their obligations and, as the contracts expire, the Company may not be able to replace them with agreements on similar terms in light of increasing competition in the markets in which the Company operates.
•The Company’s ability to effectively consummate future acquisitions will also depend on the Company’s ability to arrange the required or desired financing for acquisitions.
•The Company’s indebtedness could adversely affect its ability to raise additional capital to fund the Company’s operations or pay distributions, and its debt may be adversely affected by changes to, or replacement of, the London Interbank Offered Rate, or LIBOR.distributions.
•The operation of electric generation facilities depends on suitable meteorological conditions and involves significant risks and hazards customary to the power industry that could have a material adverse effect on the Company'sCompany’s business, financial condition, results of operations and cash flows. These facilities may operate without long-term power sales agreements.
•Maintenance, expansion and refurbishment of electric generation facilities involve significant risks that could result in unplanned power outages or reduced output.
•Supplier and/or customer concentration at certain of the Company'sCompany’s facilities may expose the Company to significant financial credit or performance risks.
•The Company currently owns, and in the future may acquire, certain assets in which the Company has limited control over management decisions and its interests in such assets may be subject to transfer or other related restrictions.
•The Company'sCompany’s assets are exposed to risks inherent in the use of interest rate swaps and forward commodity purchase contracts and the Company may be exposed to additional risks in the future if it utilizes other derivative instruments.
•The Company does not own all of the land on which its power generation or thermal assets are located, which could result in disruption to its operations. The Company’s use and enjoyment of real property rights for its projects may be adversely affected by the rights of lienholders and leaseholders that are superior to those of the grantors of those real property rights to the Company.
•The Company'sCompany’s businesses are subject to physical, market and economic risks relating to potential effects of climate change and public and governmental initiatives to address climate change.
•Risks that are beyond the Company'sCompany’s control, including but not limited to acts of terrorism or related acts of war, natural disaster, pandemics (such as the COVID-19 pandemic), inflation, supply chain disruptions, hostile cyber intrusions or other catastrophic events, could have a material adverse effect on the business, financial condition, results of operations and cash flows.
•The operation of the Company’s businesses is subject to cyber-based security and integrity risk.
•The Company relies on electric distribution and transmission facilities that it does not own or control and that are subject to transmission constraints within a number of the Company'sCompany’s regions. If these facilities fail to provide the Company with adequate transmission capacity, it may be restricted in its ability to deliver electric power to its customers and may either incur additional costs or forego revenues.
•The Company'sCompany’s costs, results of operations, financial condition and cash flows could be adversely impacted by the disruption of the fuel supplies necessary to generate power at its conventional and thermal power generation facilities.
•The Company depends on key personnel and its ability to attract and retain additional skilled management and other personnel, the loss of any of which could have a material adverse effect on the Company'sCompany’s financial condition and results of operations.
•The Company may potentially be adversely affected by emerging technologies that may over time impact capacity markets and the energy industry overall.
Risks Related to the Company’s Relationship with GIP, TotalEnergies and CEG
•GIP exercisesand TotalEnergies, through their equal ownership of CEG, the Company’s controlling shareholder of Clearway, Inc., exercise substantial influence over the Company through its position as the controlling shareholder of Clearway, Inc.Company. The Company is highly dependent on GIP, TotalEnergies and CEG.
•CEG controls the Company and has the ability to designate a majority of the members of Clearway, Inc.’s Board.
•The Company may not be able to consummate future acquisitions from CEG.
•The Company may be unable to terminate the CEG Master Services Agreement, in certain circumstances.
•If CEG terminates the CEG Master Services Agreement or defaults in the performance of its obligations under the agreement, the Company may be unable to contract with a substitute service provider on similar terms, or at all.
Risks Related to Regulation
•The Company's business is subject to restrictions resulting from environmental, health and safety laws and regulations.
•The electric generation business is subject to substantial governmental regulation, including environmental laws, and may be adversely affected by changes in laws or regulations, as well as liability under, or any future inability to comply with, existing or future regulations or other legal requirements.
•The Company's business is subject to complex and evolving U.S. laws and regulations regarding privacy and data protection.
•Government regulations providing incentives for renewable power generation could change at any time and such changes may negatively impact the Company's growth strategy.
•The profitability of certain of the Company's Thermal assets is dependent on regulatory approval.
Risks Related to the Company's Business
The ongoing coronavirus (COVID-19) pandemic or any other pandemic could adversely affect the Company’s business, financial condition and results of operations.
The ongoing coronavirus (COVID-19) outbreak, which the World Health Organization declared as a pandemic on March 11, 2020, has reached every region of the world and has resulted in widespread adverse impacts on the global economy. In response, the Company has modified certain business and workforce practices (including discontinuing all non-essential business travel, implementing a temporary work-from-home policy for employees who can execute their work remotely and encouraging employees to adhere to local and regional social distancing, more stringent hygiene and cleaning protocols across the Company’s facilities and operations and self-quarantining recommendations) to conform to government restrictions and best practices encouraged by governmental and regulatory authorities. However, the quarantine of personnel or the inability to access the Company’s facilities or customer sites could adversely affect the Company’s operations. Also, the Company has a limited number of highly skilled employees for some of its operations and relies on certain independent contractors and other service providers. If a large proportion of the Company’s employees in those critical positions, or independent contractors or other service providers to the Company or its customers were to contract COVID-19 at the same time, the Company would rely upon its business continuity plans in an effort to continue operations at its facilities, but there is no certainty that such measures will be sufficient to mitigate the adverse impact to its operations that could result from shortages of highly skilled employees, independent contractors or service providers.
There is considerable uncertainty regarding how long the COVID-19 pandemic will persist and affect economic conditions, as well as whether governmental and other measures implemented to try to slow the spread of the virus, such as large-scale travel bans and restrictions, border closures, quarantines, shelter-in-place orders and business and government shutdowns that exist as of the date of this report will be effective or whether new measures will be implemented or reinstated. Restrictions of this nature may cause the Company, its suppliers and other business counterparties to experience operational delays and delays in the delivery of materials and supplies and may cause milestones or deadlines relating to various projects to be missed. As a result, the Company could experience reductions in its sales and corresponding revenues in future periods. In addition, worsening economic conditions could result in the Company’s customers being unable or unwilling to fulfill their contractual obligations over time, or as contracts expire, to replace them with agreements on similar terms, which would impact the Company’s future financial performance. A significant decline in sales for the output the Company generates, whether due to decreases in consumer demand or disruption to its facilities or otherwise, would have a material adverse effect on the Company’s financial expectations, its financial condition, results of operations and cash flows, its ability to make distributions to its unit holders and its ability to satisfy its debt service obligations.
As of the date of this report, the Company's efforts to respond to the challenges presented by the conditions described above have allowed the Company to minimize the impacts to its business.
Additionally, the effects of COVID-19 (and its variants) or any other pandemic on the global economy could adversely affect the Company’s ability to access the capital and other financial markets, and if so, the Company may need to consider alternative sources of funding for some of its operations and for working capital, which may increase its cost of, as well as adversely impact its access to, capital. These uncertain economic conditions may also result in the inability of the Company’s customers and other counterparties to make payments to the Company, on a timely basis or at all, which could adversely affect the Company’s financial expectations, its financial condition, results of operations and cash flows, its ability to make distributions to its unit holders and its ability to satisfy its debt service obligations.
The Company cannot predict the full impact that COVID-19 and its variants will have on the Company’s financial expectations, its financial condition, results of operations and cash flows, its ability to make distributions to its unit holders and its ability to satisfy its debt service obligations at this time, due to numerous uncertainties. The ultimate impacts will depend on future developments, including, among others, the ultimate duration and persistence of the pandemic, the consequences of governmental and other measures designed to prevent the spread of the virus, the ability of governments and health care providers to timely distribute available vaccines and the efficacy of such vaccines, the duration of the outbreak, actions taken by governmental actions taken by authorities, customers, suppliers and other third parties, workforce availability and the timing and extent to which normal economic and operating conditions resume.
Certain facilities are newly constructed and may not perform as expected.
Certain of the Company's conventional and renewable assets are newly constructed. The ability of these facilities to meet the Company's performance expectations is subject to the risks inherent in newly constructed power generation facilities and the construction of such facilities, including, but not limited to, degradation of equipment in excess of the Company's expectations, system failures, and outages. The failure of these facilities to perform as the Company expects could have a material adverse effect on the Company's business, financial condition, results of operations, cash flows and its ability to pay distributions to Clearway, Inc. and CEG.
Pursuant to the Company's cash distribution policy, the Company intends to distribute a significant amount of the CAFD through regular quarterly distributions, and the Company's ability to grow and make acquisitions through cash on hand is limited.
The Company expects to distribute a significant amount of the CAFD each quarter and to rely primarily upon external financing sources, including the issuance of debt and equity securities and, if applicable, borrowings under the Company's revolving credit facility to fund acquisitions and growth capital expenditures. The Company may be precluded from pursuing otherwise attractive acquisitions if the projected short-term cash flow from the acquisition or investment is not adequate to service the capital raised to fund the acquisition or investment, after giving effect to the Company's available cash reserves. The incurrence of bank borrowings or other debt by Clearway Energy Operating LLC or by the Company's project-level subsidiaries to finance the Company’s growth strategy will result in increased interest expense and the imposition of additional or more restrictive covenants, which, in turn, may impact the cash distributions the Company makes to Clearway, Inc. and CEG.
The Company may be unable to close the Thermal Disposition.
On October 22, 2021, Clearway Energy Operating LLC entered into a Membership Interest Purchase Agreement to sell the Company’s Thermal Business to KKR, or the Thermal Disposition. The Thermal Disposition is expected to close in the first half of 2022 and is subject to certain customary closing conditions that make its completion and timing uncertain. Accordingly, there can be no assurance that the Thermal Disposition will be consummated on the anticipated schedule or at all. If the Company is unable to complete the Thermal Disposition, the Company may need to seek a new buyer or reassess the decision to sell the Thermal Business, and any such new sale would also be subject to new regulatory approvals and other conditions. Such renegotiation and conditions and the process of obtaining regulatory approvals could have the effect of delaying or impeding consummation of the sale of the Thermal Business. In addition, if the Thermal Disposition is not completed, the Company may need to raise additional capital, including the issuance of additional shares of Clearway Inc.'s common stock to raise equity capital to repay existing indebtedness that has been incurred in anticipation of the Thermal Disposition and to fund the Company’s operations or future growth investments. The future issuance of additional shares of Clearway, Inc. common stock may cause dilution of investors' ownership interest and adversely impact the value of Clearway, Inc.'s common stock. As a result, a delay or failure to consummate the Thermal Disposition could have a material adverse effect on the Company’s business, financial position or results of operations.
The Company may not be able to effectively identify or consummate any future acquisitions on favorable terms, or at all, and future acquisitions may not be accretive as a result of incorrect assumptions in the Company's evaluation of such acquisitions, unforeseen consequences or other external events beyond the Company's control.
The Company's business strategy includes growth through the acquisitions of additional generation assets (including through corporate acquisitions). This strategy depends on the Company’s ability to successfully identify and evaluate acquisition opportunities and consummate acquisitions on favorable terms. However, the number of acquisition opportunities is limited. In addition, the Company will compete with other companies for these limited acquisition opportunities, which may increase the Company’s cost of making acquisitions or cause the Company to refrain from making acquisitions at all. Some of the Company’s competitors for acquisitions are much larger than the Company with substantially greater resources. These companies may be able to pay more for acquisitions and may be able to identify, evaluate, bid for and purchase a greater number of assets than the Company’s financial or human resources permit. If the Company is unable to identify and consummate future acquisitions, it will impede the Company’s ability to execute its growth strategy and limit the Company’s ability to increase the amount of dividends paid to holders of Clearway, Inc.'s common stock.
The Company’s ability to acquire future renewable facilities may depend on the viability of renewable assets generally. These assets currently are largely contingent on public policy mechanisms including ITCs, cash grants, loan guarantees, accelerated depreciation, RPS and carbon trading plans. These mechanisms have been implemented at the state and federal levels to support the development of renewable generation, demand-side and smart grid and other clean infrastructure technologies. The availability and continuation of public policy support mechanisms will drive a significant part of the economics and viability of the Company’s growth strategy and expansion into clean energy investments.
The acquisition of companies and assets are subject to substantial risks, including the failure to identify material problems during due diligence (for which the Company may not be indemnified post-closing) and the risk of overpaying for assets (or not making acquisitions on an accretive basis). The integration and consolidation of acquisitions requires substantial human, financial and other resources and, ultimately, the Company's acquisitions may divert management’s attention from the Company's existing business concerns, disrupt the Company's ongoing business or not be successfully integrated. There can be no assurances that any future acquisitions will perform as expected or that the returns from such acquisitions will support the financing utilized to acquire them or maintain them. A failure to achieve the financial returns the Company expects when it acquires generation assets could have a material adverse effect on the Company’s ability to grow its business and make cash distributions to its unit holders. Any failure of the Company’s acquired generation assets to be accretive or difficulty in integrating such acquisition into the Company’s business could have a material adverse effect on the Company’s ability to grow its business and make cash distributions to its unit holders. As a result, the consummation of acquisitions could have a material adverse effect on the Company's business, financial condition, results of operations, cash flows and ability to pay distributions to its unit holders.
Counterparties to the Company's offtake agreements may not fulfill their obligations and, as the contracts expire, the Company may not be able to replace them with agreements on similar terms in light of increasing competition in the markets in which the Company operates.
A significant portion of the electric power the Company generates is sold under long-term offtake agreements with public utilities or industrial or commercial end-users, with a weighted average remaining duration, based on CAFD, of approximately 12 years. As of December 31, 2021, the largest customers of the Company's power generation assets, including assets in which the Company has less than a 100% membership interest, were SCE and PG&E, which represented 33% and 23%, respectively, of total consolidated revenues generated by the Company during the year ended December 31, 2021.
If, for any reason, any of the purchasers of power under these agreements are unable or unwilling to fulfill their related contractual obligations or if they refuse to accept delivery of power delivered thereunder or if they otherwise terminate such agreements prior to the expiration thereof, the Company's assets, liabilities, business, financial condition, results of operations and cash flows could be materially and adversely affected. Furthermore, to the extent any of the Company's power purchasers are, or are controlled by, governmental entities, the Company's facilities may be subject to legislative or other political action that may impair their contractual performance.
The power generation industry is characterized by intense competition and the Company's electric generation assets encounter competition from utilities, industrial companies and independent power producers, in particular with respect to uncontracted output. In recent years, there has been increasing competition among generators for offtake agreements and this has contributed to a reduction in electricity prices in certain markets characterized by excess supply above designated reserve margins. In light of these market conditions, the Company may not be able to replace an expiring or terminated agreement with an agreement on equivalent terms and conditions, including at prices that permit operation of the related facility on a profitable basis. In addition, the Company believes many of its competitors have well-established relationships with the Company's current and potential suppliers, lenders and customers, and have extensive knowledge of its target markets. As a result, these competitors may be able to respond more quickly than the Company to evolving industry standards and changing customer requirements. The adoption of more advanced technology could reduce its competitors' power production costs resulting in their having a lower cost structure than is achievable with the technologies currently employed by the Company and adversely affect its ability to compete for offtake agreement renewals. If the Company is unable to replace an expiring or terminated offtake agreement, the affected facility may temporarily or permanently cease operations. External events, such as a severe economic downturn or force majeure events, could also impair the ability of some counterparties to the Company's offtake agreements and other customer agreements to pay for energy and/or other products and services received.
The Company's inability to enter into new or replacement offtake agreements or to compete successfully against current and future competitors in the markets in which the Company operates could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.
The Company’s ability to effectively consummate future acquisitions will also depend on the Company’s ability to arrange the required or desired financing for acquisitions.
The Company may not have sufficient availability under the Company’s credit facilities or have access to project-level financing on commercially reasonable terms when acquisition opportunities arise. An inability to obtain the required or desired financing could significantly limit the Company’s ability to consummate future acquisitions and effectuate the Company’s growth strategy. If financing is available, utilization of the Company’s credit facilities or project-level financing for all or a portion of the purchase price of an acquisition could significantly increase the Company’s interest expense, impose additional or more restrictive covenants and reduce CAFD. The Company’s ability to consummate future acquisitions may also depend on the Company’s ability to obtain any required regulatory approvals for such acquisitions, including, but not limited to, approval by FERC under Section 203 of the FPA.
The Company’s indebtedness could adversely affect its ability to raise additional capital to fund the Company’s operations or pay distributions. It could also expose the Company to the risk of increased interest rates and limit the Company’s ability to react to changes in the economy or the Company’s industry as well as impact the Company’s results of operations, financial condition and cash flows.
As of December 31, 2021, the Company had approximately $7,779 million of total consolidated indebtedness, $5,073 million of which was incurred by the Company's non-guarantor subsidiaries. In addition, the Company’s share of its unconsolidated affiliates’ total indebtedness and letters of credit outstanding as of December 31, 2021, totaled approximately $345 million and $37 million, respectively (calculated as the Company’s unconsolidated affiliates’ total indebtedness as of such date multiplied by the Company’s percentage membership interest in such assets).
The Company’s substantial debt could have important negative consequences on the Company’s financial condition, including:
•increasing the Company’s vulnerability to general economic and industry conditions;
•requiring a substantial portion of the Company’s cash flow from operations to be dedicated to the payment of principal and interest on the Company’s indebtedness, therefore reducing the Company’s ability to pay distributions to Clearway, Inc. and CEG or to use the Company’s cash flow to fund its operations, capital expenditures and future business opportunities;
•limiting the Company’s ability to enter into long-term power sales or fuel purchases which require credit support;
•limiting the Company’s ability to fund operations or future acquisitions;
•restricting the Company’s ability to make certain distributions to Clearway, Inc. and CEG and the ability of the Company’s subsidiaries to make certain distributions to it, in light of restricted payment and other financial covenants in the Company’s credit facilities and other financing agreements;
•exposing the Company to the risk of increased interest rates because certain of the Company’s borrowings, which may include borrowings under the Company’s revolving credit facility, are at variable rates of interest;
•limiting the Company’s ability to obtain additional financing for working capital including collateral postings, capital expenditures, debt service requirements, acquisitions and general corporate or other purposes; and
•limiting the Company’s ability to adjust to changing market conditions and placing it at a competitive disadvantage compared to the Company’s competitors who have less debt.
The Company's revolving credit facility contains financial and other restrictive covenants that limit the Company’s ability to return capital to unit holders or otherwise engage in activities that may be in the Company’s long-term best interests. The Company’s inability to satisfy certain financial covenants could prevent the Company from paying cash distributions, and the Company’s failure to comply with those and other covenants could result in an event of default which, if not cured or waived, may entitle the related lenders to demand repayment or enforce their security interests, which could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flows. In addition, failure to comply with such covenants may entitle the related lenders to demand repayment and accelerate all such indebtedness.
The agreements governing the Company’s project-level financing contain financial and other restrictive covenants that limit the Company’s project subsidiaries’ ability to make distributions to the Company or otherwise engage in activities that may be in the Company’s long-term best interests. The project-level financing agreements generally prohibit distributions from the project entities to the Company unless certain specific conditions are met, including the satisfaction of certain financial ratios. The Company’s inability to satisfy certain financial covenants may prevent cash distributions by the particular project(s) to it and, the Company’s failure to comply with those and other covenants could result in an event of default which, if not cured or waived may entitle the related lenders to demand repayment or enforce their security interests, which could have a material adverse effect on the Company’s business, results of operations and financial condition. In addition, failure to comply with such covenants may entitle the related lenders to demand repayment and accelerate all such indebtedness. If the Company is unable to make distributions from the Company’s project-level subsidiaries, it would likely have a material adverse effect on the Company’s ability to pay distributions to Clearway, Inc. and CEG.
Letter of credit facilities to support project-level contractual obligations generally have a limited term that may require future renewal, at which time the Company or relevant project-level subsidiary will need to satisfy applicable financial ratios and covenants. If the Company is unable to renew the Company’s letters of credit as expected or replace them with letters of credit under different facilities on favorable terms or at all, the Company may experience a material adverse effect on its business, financial condition, results of operations and cash flows. Furthermore, such inability may constitute a default under certain project-level financing arrangements, restrict the ability of the project-level subsidiary to make distributions to it and/or reduce the amount of cash available at such subsidiary to make distributions to the Company.
In addition, the Company’s ability to arrange financing, either at the corporate level or at a non-recourse project-level subsidiary, and the costs of such capital, are dependent on numerous factors, including:
•general economic and capital market conditions;
•credit availability from banks and other financial institutions;
•investor confidence in the Company, its partners, Clearway, Inc. (as the Company's sole managing member), or GIP, through CEG, as Clearway, Inc.'s principal stockholder (on a combined voting basis) and the regional wholesale power markets;
•the Company’s financial performance and the financial performance of the Company subsidiaries;
•the Company’s level of indebtedness and compliance with covenants in debt agreements;
•maintenance of acceptable project credit ratings or credit quality;
•cash flow; and
•provisions of tax and securities laws that may impact raising capital.
The Company may not be successful in obtaining additional capital for these or other reasons. Furthermore, the Company may be unable to refinance or replace project-level financing arrangements or other credit facilities on favorable terms or at all upon the expiration or termination thereof. The Company's failure, or the failure of any of the Company’s projects, to obtain additional capital or enter into new or replacement financing arrangements when due may constitute a default under such existing indebtedness and may have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.
Changes in the method of determining the London Interbank Offered Rate, or LIBOR, or the replacement of LIBOR with an alternative reference rate, may adversely affect interest expense related to outstanding debt.
Amounts drawn under the Company's revolving credit facility and certain of the Company's project-level debt facilitiescurrently bear interest at rates based on LIBOR. On July 27, 2017, the Financial Conduct Authority in the United Kingdom announced that it would phase out LIBOR as a benchmark by the end of 2021. On November 30, 2020, ICE Benchmark Administration Limited, the administrator of LIBOR, with the support of the United States Federal Reserve and the United Kingdom’s Financial Conduct Authority, announced plans to consult on ceasing publication of USD LIBOR on December 31, 2021 for only the one week and two month USD LIBOR tenors, and on June 30, 2023 for all other USD LIBOR tenors. While this announcement extends the transition period to June 30, 2023, the United States Federal Reserve concurrently issued a statement advising banks to stop new LIBOR issuances by the end of 2021. In light of these recent announcements, the future of LIBOR at this time is uncertain and any changes in the methods by which LIBOR is determined or regulatory activity related to LIBOR’s phase-out could cause LIBOR to perform differently than in the past or cease to exist. While the Company's revolving credit facility includes a mechanism to amend the facilities to reflect the establishment of an alternative rate of interest upon the occurrence of certain events related to the phase-out of LIBOR, many of the Company's project-level debt facilities and swap arrangements do not. The Company has not yet pursued technical amendments or other contractual alternatives to address this matter with respect to all its existing debt facilities and swap arrangements and is continuing to evaluate the impact of LIBOR’s expected replacement. If no such amendments or other contractual alternatives are established on or prior to the phase-out of LIBOR, interest under the Company's revolving credit facility and other project-level debt facilities will bear interest at higher rates based on the prime rate until such amendments or other contractual amendments are established. Even if the Company has entered into interest rate swaps or other derivative instruments for purposes of managing its interest rate exposure or has otherwise amended its interest rate swaps or other derivative instruments to reflect an alternative reference rate, these hedging strategies may not be effective as a result of the replacement or phasing out of LIBOR, and the Company may incur losses as a result. The potential increase in the Company’s interest expense as a result of the phase-out of LIBOR and uncertainty as to the nature of the alternative reference rates could have an adverse effect on the Company's business, financial condition, results of operations and cash flows.
The Company’s proceeds from “Green Bonds” may not satisfy investor criteria and expectations regarding environmental impact and sustainability performance.
Certain of the Company’s Senior Notes are “Green Bonds,” which require that an amount equal to the net proceeds from the sale of such Senior Notes must be allocated to finance or refinance, in part or in full, new and existing projects and assets meeting certain eligibility criteria under the Company's green bond framework. There is no assurance that the eligible projects to which the Company allocates proceeds from such Senior Notes will satisfy, or continue to satisfy, investor criteria and expectations regarding environmental impact and sustainability performance, and no assurance is given that the use or allocation will satisfy present or future investor expectations or requirements, voluntary taxonomies or standards regarding any investment criteria or guidelines with which investors or their investments are required to comply, whether by any present or future applicable laws or regulations, by their own governing rules or investment portfolio mandates, ratings criteria, voluntary taxonomies or standards or other independent expectations. The market price of such Senior Notes may be impacted by any failure by the Company to satisfy these present or future investor expectations or requirements.
Certain of the Company's long-term bilateral contracts result from state-mandated procurements and could be declared invalid by a court of competent jurisdiction.
A portion of the Company's revenues are derived from long-term bilateral contracts with utilities that are regulated by their respective states, and have been entered into pursuant to certain state programs. Certain long-term contracts that other companies have with state-regulated utilities have been challenged in federal court and have been declared unconstitutional on the grounds that the rate for energy and capacity established by the contracts impermissibly conflicts with the rate for energy and capacity established by FERC pursuant to the FPA. If certain of the Company's state-mandated agreements with utilities are ever held to be invalid or unenforceable due to the financial conditions or other conditions of such utility, the Company may be unable to replace such contracts, which could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.
The generation of electric energy from solar and wind energy sources depends heavily on suitable meteorological conditions.
If solar or wind conditions are unfavorable, the Company's electricity generation and revenue from renewable generation facilities may be substantially below the Company's expectations. The electricity produced and revenues generated by a solar or wind energy generation facility is highly dependent on suitable solar or wind conditions, as applicable, and associated weather conditions, which are beyond the Company's control. Furthermore, components of the Company's systems, such as solar panels and inverters, could be damaged by severe weather, such as wildfires, hailstorms, tornadoes or freezing temperatures and other winter weather conditions. In addition, replacement and spare parts for key components may be difficult or costly to acquire or may be unavailable. Unfavorable weather and atmospheric conditions could impair the effectiveness of the Company's assets or reduce their output beneath their rated capacity or require shutdown of key equipment, impeding operation of the Company's renewable assets. For example, in February 2021, the Company's wind projects in Texas were unable to operate and experienced outages for a few days as a result of the extreme winter weather conditions. In addition, climate change may have the long-term effect of changing wind patterns at the Company's projects. Changing wind patterns could cause changes in expected electricity generation. These events could also degrade equipment or components and the interconnection and transmission facilities’ lives or maintenance costs.
Although the Company bases its investment decisions with respect to each renewable generation facility on the findings of related wind and solar studies conducted on-site prior to construction or based on historical conditions at existing facilities, actual climatic conditions at a facility site, particularly wind conditions, may not conform to the findings of these studies and may be affected by variations in weather patterns, including any potential impact of climate change. Therefore, the Company's solar and wind energy facilities may not meet anticipated production levels or the rated capacity of the Company's generation assets, which could adversely affect the Company's business, financial condition, results of operations and cash flows.
Operation of electric generation facilities involves significant risks and hazards customary to the power industry that could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.
The ongoing operation of the Company's facilities involves risks that include the breakdown or failure of equipment or processes or performance below expected levels of output or efficiency due to wear and tear, latent defect, design error or operator error or force majeure events, among other things. Operation of the Company's facilities also involves risks that the Company will be unable to transport its products to its customers in an efficient manner due to a lack of transmission capacity. Unplanned outages of generating units, including extensions of scheduled outages due to mechanical failures or other problems, occur from time to time and are an inherent risk of the business. Unplanned outages typically increase operation and maintenance expenses, capital expenditures and may reduce revenues as a result of selling fewer MWh or require the Company to incur significant costs as a result of obtaining replacement power from third parties in the open market to satisfy forward power sales obligations. The Company's inability to operate its electric generation assets efficiently, manage capital expenditures and costs and generate earnings and cash flow from the Company's asset-based businesses could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows. While the Company maintains insurance, obtains warranties from vendors and obligates contractors to meet certain performance levels, the proceeds of such insurance, warranties or performance guarantees may not cover the Company's lost revenues, increased expenses or liquidated damages payments should it experience equipment breakdown or non-performance by contractors or vendors. The Company maintains an amount of insurance protection that it considers adequate but cannot provide any assurance that the Company's insurance will be sufficient or effective under all circumstances and against all hazards or liabilities to which the Company may be subject. Furthermore, the Company's insurance coverage is subject to deductibles, caps, exclusions and other limitations. A loss for which the Company is not fully insured (which may include a significant judgment against any facility or facility operator) could have a material adverse effect on the Company's business, financial condition, results of operations or cash flows. Further, due to rising insurance costs and changes in the insurance markets, the Company cannot provide any assurance that its insurance coverage will continue to be available at all or at rates or on terms similar to those presently available. Any losses not covered by insurance could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.
Power generation involves hazardous activities, including acquiring, transporting and unloading fuel, operating large pieces of rotating equipment and delivering electricity to transmission and distribution systems. In addition to natural risks such as earthquake, flood, lightning, hurricane and wind, other hazards, such as fire, explosion, structural collapse and machinery failure are inherent risks in the Company's operations. These and other hazards can cause significant personal injury or loss of life, severe damage to and destruction of property, plant and equipment and contamination of, or damage to, the environment and suspension of operations. To the extent an event was not covered by insurance policies, such incidents could subject the Company to substantial liabilities arising from emergency response, environmental cleanup and restoration costs, claims made by neighboring landowners and other third parties for personal injury and property damage, and fines or penalties for any related violations of environmental laws or regulations.
The Company’s facilities may operate, wholly or partially, without long-term power sales agreements.
The Company’s facilities may operate without long-term power sales agreements for some or all of their generating capacity and output and therefore be exposed to market fluctuations. Without the benefit of long-term power sales agreements for the facilities, the Company cannot be sure that it will be able to sell any or all of the power generated by the facilities at commercially attractive rates or that the facilities will be able to operate profitably. This could lead to less predictable revenues, future impairments of the Company's property, plant and equipment or to the closing of certain of its facilities, resulting in economic losses and liabilities, which could have a material adverse effect on the Company's results of operations, financial condition or cash flows.
Maintenance, expansion and refurbishment of electric generation facilities involve significant risks that could result in unplanned power outages or reduced output.
The Company's facilities may require periodic upgrading and improvement. Any unexpected operational or mechanical failure, including failure associated with breakdowns and forced outages, could reduce the Company's facilities' generating capacity below expected levels, reducing the Company's revenues and jeopardizing the Company's ability to pay distributions to Clearway, Inc. and CEG at expected levels or at all. Degradation of the performance of the Company's solar facilities above levels provided for in the related offtake agreements may also reduce the Company's revenues. Unanticipated capital expenditures associated with maintaining, upgrading or repairing the Company's facilities may also reduce profitability.
If the Company makes any major modifications to its conventional power generation facilities, it may be required to install the best available control technology or to achieve the lowest achievable emission rates as such terms are defined under the new source review provisions of the Clean Air Act in the future. Any such modifications could likely result in substantial additional capital expenditures. The Company may also choose to repower, refurbish or upgrade its facilities based on its assessment that such activity will provide adequate financial returns. Such facilities require time for development and capital expenditures before commencement of commercial operations, and key assumptions underpinning a decision to make such an investment may prove incorrect, including assumptions regarding construction costs, timing, available financing and future fuel and power prices. These events could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.
Supplier and/or customer concentration at certain of the Company's facilities may expose the Company to significant financial credit or performance risks.
The Company often relies on a single contracted supplier or a small number of suppliers for the provision of fuel, transportation of fuel, equipment, technology and/or other services required for the operation of certain facilities. In addition, certain of the Company's suppliers provide long-term warranties with respect to the performance of their products or services. If any of these suppliers cannot perform under their agreements with the Company, or satisfy their related warranty obligations, the Company will need to utilize the marketplace to provide or repair these products and services. There can be no assurance that the marketplace can provide these products and services as, when and where required. The Company may not be able to enter into replacement agreements on favorable terms or at all. If the Company is unable to enter into replacement agreements to provide for fuel, equipment, technology and other required services, it would seek to purchase the related goods or services at market prices, exposing the Company to market price volatility and the risk that fuel and transportation may not be available during certain periods at any price. The Company may also be required to make significant capital contributions to remove, replace or redesign equipment that cannot be supported or maintained by replacement suppliers, which could have a material adverse effect on the business, financial condition, results of operations, credit support terms and cash flows.
In addition, potential or existing customers at the Company’s district energy centers and combined heat and power plants, or the Energy Centers, may opt for on-site systems in lieu of using the Company’s Energy Centers, either due to corporate policies regarding the allocation of capital, unique situations where an on-site system might in fact prove more efficient, because of previously committed capital in systems that are already on-site, or otherwise. At times, the Company relies on a single customer or a few customers to purchase all or a significant portion of a facility's output, in some cases under long-term agreements that account for a substantial percentage of the anticipated revenue from a given facility.
The failure of any supplier to fulfill its contractual obligations to the Company or the Company’s loss of potential or existing customers could have a material adverse effect on its financial results. Consequently, the financial performance of the Company's facilities is dependent on the credit quality of, and continued performance by, the Company's suppliers and vendors and the Company’s ability to solicit and retain customers.
The Company currently owns, and in the future may acquire, certain assets in which the Company has limited control over management decisions and its interests in such assets may be subject to transfer or other related restrictions.
As described in Item 15 — Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, the Company has limited control over the operation of certain of its assets, because the Company beneficially owns less than a majority of the membership interests in such assets. The Company may seek to acquire additional assets in which it owns less than a majority of the related membership interests in the future. In these investments, the Company will seek to exert a degree of influence with respect to the management and operation of assets in which it owns less than a majority of the membership interests by negotiating to obtain positions on management committees or to receive certain limited governance rights, such as rights to veto significant actions. However, the Company may not always succeed in such negotiations. The Company may be dependent on its co-venturers to operate such assets. The Company's co-venturers may not have the level of experience, technical expertise, human resources management and other attributes necessary to operate these assets optimally. In addition, conflicts of interest may arise in the future between theCompany and its unit holders, on the one hand, and the Company's co-venturers, on the other hand, where the Company's co-venturers' business interests are inconsistent with the interests of the Company and its unit holders. Further, disagreements or disputes between the Company and its co-venturers could result in litigation, which could increase expenses and potentially limit the time and effort the Company's officers and directors are able to devote to the business.
The approval of co-venturers may also be required for the Company to receive distributions of funds from assets or to sell, pledge, transfer, assign or otherwise convey its interest in such assets, or for the Company to acquire GIP's or CEG's interests in such co-ventures as an initial matter. Alternatively, the Company's co-venturers may have rights of first refusal or rights of first offer in the event of a proposed sale or transfer of the Company's interests in such assets. These restrictions may limit the price or interest level for interests in such assets, in the event the Company wants to sell such interests.
Furthermore, certain of the Company's facilities are operated by third-party operators. To the extent that third-party operators do not fulfill their obligations to manage operations of the facilities or are not effective in doing so, the amount of CAFD may be adversely affected.
The Company's assets are exposed to risks inherent in the use of interest rate swaps and forward commodity purchase contracts and the Company may be exposed to additional risks in the future if it utilizes other derivative instruments.
The Company uses interest rate swaps to manage interest rate risk. In addition, the Company uses forward commodity purchase contracts to hedge its limited commodity exposure with respect to the Company's district energy assets. If the Company elects to enter into such commodity hedges, the related asset could recognize financial losses on these arrangements as a result of volatility in the market values of the underlying commodities or if a counterparty fails to perform under a contract. If actively quoted market prices and pricing information from external sources are not available, the valuation of these contracts would involve judgment or the use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these contracts. If the values of these financial contracts change in a manner that the Company does not anticipate, or if a counterparty fails to perform under a contract, it could harm the business, financial condition, results of operations and cash flows.
The Company does not own all of the land on which its power generation or thermal assets are located, which could result in disruption to its operations.
The Company does not own all of the land on which its power generation or thermal assets are located and the Company is, therefore, subject to the possibility of less desirable terms and increased costs to retain necessary land use if it does not have valid leases or rights-of-way or if such rights-of-way lapse or terminate. Although the Company has obtained rights to construct and operate these assets pursuant to related lease arrangements, the rights to conduct those activities are subject to certain exceptions, including the term of the lease arrangement. The Company is also at risk of condemnation on land it owns. The loss of these rights, through the Company's inability to renew right-of-way contracts, condemnation or otherwise, may adversely affect the Company's ability to operate its generation and thermal infrastructure assets.
The Company’s use and enjoyment of real property rights for its projects may be adversely affected by the rights of lienholders and leaseholders that are superior to those of the grantors of those real property rights to the Company.
Solar and wind projects generally are, and are likely to be, located on land occupied by the project pursuant to long-term easements and leases. The ownership interests in the land subject to these easements and leases may be subject to mortgages securing loans or other liens (such as tax liens) and other easement and lease rights of third parties (such as leases of oil or mineral rights) that were created prior to the project’s easements and leases. As a result, the project’s rights under these easements or leases may be subject, and subordinate, to the rights of those third parties. The Company performs title searches and obtains title insurance to protect itself against these risks. Such measures may, however, be inadequate to protect the Company against all risk of loss of its rights to use the land on which the wind projects are located, which could have a material adverse effect on the Company’s business, financial condition and results of operations.
The Company's businesses are subject to physical, market and economic risks relating to potential effects of climate change and public and governmental initiatives to address climate change.
Climate change creates uncertainty in weather and other environmental conditions, including temperature and precipitation levels, and thus may affect consumer demand for electricity. For example, milder than normal weather can reduce demand for electricity and gas distribution services. In addition, the potential physical effects of climate change, such as increased frequency and severity of storms, cloud coverage, precipitation, floods and other climatic events, could disrupt the Company's operations and supply chain, and cause them to incur significant costs in preparing for or responding to these effects. These or other meteorological changes could lead to increased operating costs, capital expenses or power purchase costs.
Furthermore, governmental, scientific and public concern over the threat of climate change arising from GHG emissions may limit the Company's access to natural gas or decrease demand for energy generated by the Company’s conventional assets. State, national and foreign governments and agencies continue to evaluate, and in some instances adopt, climate-related legislation and other regulatory initiatives that would restrict GHG emissions. Changes in environmental requirements related to GHG, climate change and alternative energy sources may impact demand for the Company's services. For example, the Build Back Better Act, passed by the U.S. House of Representatives and supported by President Biden, includes incentives to increase wind and solar electric generation and encourage consumers to use these alternative energy sources. While this could benefit the Company by increasing the demand for the Company's solar or wind energy, the Company could experience delayed or cancelled projects and/or reduced production and demand for energy generated by the Company’s conventional assets. At this time, it is uncertain whether, and in what form, the Build Back Better Act may become law. However, the Build Back Better Act or similar state or federal initiatives to incentivize a shift away from fossil fuels could reduce demand for energy generated by fossil fuels, and therefore have an adverse effect on the Company’s business, financial condition and results of operations.
Lastly, companies across all industries are facing increased scrutiny from the public, stakeholders and government agencies related to their environmental, social, and governance (ESG) practices and commitments to address climate change. In recent years, investor advocacy groups, institutional investors, investment funds, and other influential investors have placed increasing importance on ESG practices. Increased focus and activism related to ESG and similar matters may hinder access to capital, as investors may decide to reallocate capital or to not commit capital as a result of their assessment of a company’s ESG practices. While the Company is committed to engaging with its stakeholders on ESG practices in a proactive, holistic and integrated manner, changes in the public or stakeholder sentiment could impact the Company's ability to fund its conventional assets, or decrease the demand for the energy generated by these assets.
Risks that are beyond the Company's control, including but not limited to acts of terrorism or related acts of war, natural disaster, inflation, supply chain disruptions, hostile cyber intrusions or other catastrophic events, could have a material adverse effect on the business, financial condition, results of operations and cash flows.
The Company's generation facilities that were acquired or those that the Company otherwise acquires or constructs and the facilities of third parties on which they rely may be targets of terrorist activities, as well as events occurring in response to or in connection with them, that could cause environmental repercussions and/or result in full or partial disruption of the facilities ability to generate, transmit, transport or distribute electricity or natural gas. Strategic targets, such as energy-related facilities, may be at greater risk of future terrorist activities than other domestic targets. Inflation, disruption in global and domestic supply chains, and other economic conditions could negatively impact the Company’s business in a manner that could adversely affect the Company's results of operations and financial condition. Hostile cyber intrusions, including those targeting information systems as well as electronic control systems used at the generating plants and for the related distribution systems, could severely disrupt business operations and result in loss of service to customers, as well as create significant expense to repair security breaches or system damage.
Furthermore, certain of the Company's power generation and thermal assets are located in active earthquake zones in California and Arizona, and certain project companies and suppliers conduct their operations in the same region or in other locations that are susceptible to natural disasters. In addition, California and some of the locations where certain suppliers are located, from time to time, have experienced shortages of water, electric power and natural gas. The occurrence of a natural disaster, such as an earthquake, wildfire, drought, flood or localized extended outages of critical utilities or transportation systems, or any critical resource shortages, affecting the Company or its suppliers, could cause a significant interruption in the business, damage or destroy the Company's facilities or those of its suppliers or the manufacturing equipment or inventory of the Company's suppliers. Any such terrorist acts, environmental repercussions or disruptions or natural disasters could result in a significant decrease in revenues or significant reconstruction or remediation costs, beyond what could be recovered through insurance policies, which could have a material adverse effect on the business, financial condition, results of operations and cash flows.
The operation of the Company’s businesses is subject to cyber-based security and integrity risk.
Numerous functions affecting the efficient operation of the Company’s businesses depend on the secure and reliable storage, processing and communication of electronic data and the use of sophisticated computer hardware and software systems. The operation of the Company's generating assets relies on cyber-based technologies and has been the target of disruptive actions. Potential disruptive actions could result from cyber-attack or cyber intrusion, including by computer hackers, foreign governments and cyber terrorists, or otherwise be compromised by unintentional events with respect to the Company or any of its contractors or customers. As a result, operations could be interrupted, property could be damaged and sensitive customer information could be lost or stolen, causing the Company to incur significant losses of revenues, other substantial liabilities and damages, costs to replace or repair damaged equipment and damage to the Company's reputation. In addition, the Company may experience increased capital and operating costs to implement increased security for its cyber systems and generating assets.
The Company relies on electric distribution and transmission facilities that it does not own or control and that are subject to transmission constraints within a number of the Company's regions. If these facilities fail to provide the Company with adequate transmission capacity, it may be restricted in its ability to deliver electric power to its customers and may either incur additional costs or forego revenues.
The Company depends on electric distribution and transmission facilities owned and operated by others to deliver the wholesale power it will sell from its electric generation assets to its customers. A failure or delay in the operation or development of these facilities or a significant increase in the cost of the development of such facilities could result in lost revenues. Such failures or delays could limit the amount of power the Company's operating facilities deliver or delay the completion of the Company's construction projects. Additionally, such failures, delays or increased costs could have a material adverse effect on the business, financial condition and results of operations. If a region's power transmission infrastructure is inadequate, the Company's recovery of wholesale costs and profits may be limited. If restrictive transmission price regulation is imposed, the transmission companies may not have a sufficient incentive to invest in expansion of transmission infrastructure. The Company also cannot predict whether distribution or transmission facilities will be expanded in specific markets to accommodate competitive access to those markets. In addition, certain of the Company's operating facilities' generation of electricity may be curtailed without compensation due to transmission limitations or limitations on the electricity grid's ability to accommodate intermittent and other electricity generating sources, reducing the Company's revenues and impairing its ability to capitalize fully on a particular facility's generating potential. Such curtailments could have a material adverse effect on the business, financial condition, results of operations and cash flows. Furthermore, economic congestion on transmission networks in certain of the markets in which the Company operates may occur and the Company may be deemed responsible for congestion costs. If the Company were liable for such congestion costs, its financial results could be adversely affected.
The Company's costs, results of operations, financial condition and cash flows could be adversely impacted by the disruption of the fuel supplies necessary to generate power at its conventional and thermal power generation facilities.
Delivery of fossil fuels to fuel the Company's conventional and thermal generation facilities is dependent upon the infrastructure (including natural gas pipelines) available to serve each such generation facility as well as upon the continuing financial viability of contractual counterparties. As a result, the Company is subject to the risks of disruptions or curtailments in the production of power at these generation facilities if a counterparty fails to perform or if there is a disruption in the fuel delivery infrastructure.
The Company depends on key personnel and its ability to attract and retain additional skilled management and other personnel, the loss of any of which could have a material adverse effect on the Company's financial condition and results of operations.
The Company believes its current operations and future success depend largely on the continued services of key personnel that it employs. Although the Company currently has access to the resources of CEG, the loss of key personnel employed by the Company or CEG could have a material adverse effect on the Company’s financial condition and results of operations.
The Company may potentially be adversely affected by emerging technologies that may over time impact capacity markets and the energy industry overall.
Research and development activities are ongoing in the Company's industry to provide alternative and more efficient technologies to produce power, including wind, photovoltaic (solar) cells, hydrogen, energy storage, and improvements in traditional technologies and equipment, such as more efficient gas turbines. Advances in these or other technologies could reduce the costs of power production to a level below what the Company has currently forecasted, which could adversely affect its cash flows, results of operations or competitive position.
Some emerging technologies, such as distributed renewable energy technologies, broad consumer adoption of electric vehicles and energy storage devices, could affect the price of energy. These emerging technologies may affect the financial viability of utility counterparties and could have significant impacts on market prices, which could ultimately have a material adverse effect on the Company’s financial condition, results of operations and cash flows.
Risks Related to the Company's Relationships with GIP and CEG
GIP, through its ownership of CEG, exercises substantial influence over the Company through its position as controlling shareholder of Clearway, Inc. The Company is highly dependent on GIP and CEG.
GIP, through its ownership of CEG, owns all of Clearway, Inc.'s outstanding Class B and Class D common stock. Clearway, Inc.'s outstanding Class B and Class D common stock is entitled to one vote per share and 1/100th of a vote per share, respectively. As a result of its ownership of Clearway, Inc.'s Class B and Class D common stock, GIP indirectly owned 54.93% of the combined voting power of Clearway, Inc.’s common stock as of December 31, 2021. Clearway, Inc., through its holdings of Class A units and Class C units, owned a 57.65% economic interest in the Company as of December 31, 2021. Additionally, GIP, through CEG's holdings of Class B units and Class D units, owned the remaining 42.35% economic interest in the Company as of December 31, 2021. As a result of this ownership, GIP has a substantial influence on the Company's affairs.
Furthermore, the Company depends on certain services provided by or under the direction of CEG under the CEG Master Services Agreement, including numerous processes related to the Company's internal control over financial reporting. CEG personnel and support staff that provide services to the Company under the CEG Master Services Agreement are not required to, and the Company does not expect that they will, have as their primary responsibility the management and administration of the Company or to act exclusively for the Company and the CEG Master Services Agreement does not require any specific individuals to be provided by CEG. Under the CEG Master Services Agreement, CEG has the discretion to determine which of its employees perform assignments required to be provided to the Company. Any failure to effectively manage the Company's processes related to internal controls over financial reporting, operations or to implement its strategy could have a material adverse effect on the business, financial condition, results of operations and cash flows. The CEG Master Services Agreement will continue in perpetuity, until terminated in accordance with its terms.
The Company also depends upon CEG and third parties for the provision of management, administration, O&M and certain other services at certain of the Company's facilities. Any failure by CEG or third parties to perform its requirements under these arrangements or the failure by the Company to identify and contract with replacement service providers, if required, could adversely affect the operation of the Company's facilities and have a material adverse effect on the business, financial condition, results of operations and cash flows.
GIP and its affiliates control the Company and have the ability to designate a majority of the members of Clearway, Inc.'s Board.
Due to GIP's approximate 54.93% combined voting power in Clearway, Inc., the ability of other holders of Clearway, Inc.’s Class A and Class C common stock to exercise control over the corporate governance of the Company is limited. GIP and its affiliates have a substantial influence on Clearway, Inc.’s affairs and its voting power constitutes a large percentage of any quorum of Clearway, Inc.’s stockholders voting on any matter requiring the approval of Clearway, Inc.’s stockholders. Such matters include the election of directors, the adoption of amendments to Clearway, Inc.'s amended and restated certificate of incorporation and fourth amended and restated bylaws and approval of mergers or sale of all or substantially all of its assets. This concentration of ownership may also have the effect of delaying or preventing a change in control of Clearway, Inc. or discouraging others from making tender offers for Clearway, Inc.'s shares. In addition, GIP has the right to elect all of Clearway, Inc.'s directors. GIP and its affiliates may hold certain interests that are different from those of the Company or other holders of Clearway, Inc.'s Class A and Class C common stock and there is no assurance that GIP and its affiliates will exercise its control over the Company in a manner that is consistent with the Company’s interests or those of the holders of Clearway, Inc.'s Class A and Class C common stock.
The Company may not be able to consummate future acquisitions from CEG.
The Company's ability to grow through acquisitions depends, in part, on CEG's ability to identify and present the Company with acquisition opportunities. Although CEG has agreed, pursuant to the CEG ROFO Agreement, to grant the Company a right of first offer with respect to certain power generation assets that CEG may elect to sell in the future, CEG is under no obligation to sell any such power generation assets or to accept any related offers from the Company. In addition, CEG has not agreed to commit any minimum level of dedicated resources for the pursuit of renewable power-related acquisitions. There are a number of factors which could materially and adversely impact the extent to which suitable acquisition opportunities are made available from CEG, including that the same professionals within CEG's organization that are involved in acquisitions that are suitable for the Company have responsibilities within CEG's broader asset management business, which may include sourcing acquisition opportunities for CEG. Limits on the availability of such individuals will likewise result in a limitation on the availability of acquisition opportunities for the Company. In making these determinations, CEG may be influenced by factors that result in a misalignment with the Company's interests or conflict of interest.
The Company may be unable to terminate the CEG Master Services Agreement, in certain circumstances.
The CEG Master Services Agreement provides that the Company may terminate the agreement upon 30 days prior written notice to CEG upon the occurrence of any of the following: (i) CEG defaults in the performance or observance of any material term, condition or covenant contained therein in a manner that results in material harm to the Company and the default continues unremedied for a period of 30 days after written notice thereof is given to CEG; (ii) CEG engages in any act of fraud, misappropriation of funds or embezzlement that results in material harm to the Company; (iii) CEG is grossly negligent in the performance of its duties under the agreement and such negligence results in material harm to the Company; or (iv) upon the happening of certain events relating to the bankruptcy or insolvency of CEG. Furthermore, if the Company requests an amendment to the scope of services provided by CEG under the CEG Master Services Agreement and is not able to agree with CEG as to a change to the service fee resulting from a change in the scope of services within 180 days of the request, the Company will be able to terminate the agreement upon 30 days prior notice to CEG. The Company will not be able to terminate the agreement for any other reason, including if CEG experiences a change of control, and the agreement continues in perpetuity, until terminated in accordance with its terms. If CEG's performance does not meet the expectations of investors, and the Company is unable to terminate the CEG Master Services Agreement, the market price of the Class A and Class C common stock could suffer.
If CEG terminates the CEG Master Services Agreement or defaults in the performance of its obligations under the agreement, the Company may be unable to contract with a substitute service provider on similar terms, or at all.
The Company relies on CEG to provide certain services under the CEG Master Services Agreement. The CEG Master Services Agreement provides that CEG may terminate the agreement upon 180 days prior written notice of termination to the Company if the Company defaults in the performance or observance of any material term, condition or covenant contained in the agreement in a manner that results in material harm and the default continues unremedied for a period of 30 days after written notice of the breach is given. If CEG terminates the Management Services Agreement or defaults in the performance of its obligations under the agreement, the Company may be unable to contract with CEG or a substitute service provider on similar terms or at all, and the costs of substituting service providers may be substantial. In addition, in light of CEG's familiarity with the Company's assets, a substitute service provider may not be able to provide the same level of service due to lack of pre-existing synergies.
The liability of CEG is limited under the Company's arrangements with it and the Company has agreed to indemnify CEG against claims that it may face in connection with such arrangements, which may lead CEG to assume greater risks when making decisions relating to the Company than it otherwise might if acting solely for its own account.
Under the CEG Master Services Agreement, CEG does not assume any responsibility other than to provide or arrange for the provision of the services described in the CEG Master Services Agreement in good faith. In addition, under the CEG Master Services Agreement, the liability of CEG and its affiliates is limited to the fullest extent permitted by law to conduct involving bad faith, fraud, willful misconduct or gross negligence or, in the case of a criminal matter, action that was known to have been unlawful. In addition, the Company has agreed to indemnify CEG to the fullest extent permitted by law from and against any claims, liabilities, losses, damages, costs or expenses incurred by an indemnified person or threatened in connection with the Company's operations, investments and activities or in respect of or arising from the CEG Master Services Agreement or the services provided by CEG, except to the extent that the claims, liabilities, losses, damages, costs or expenses are determined to have resulted from the conduct in respect of which such persons have liability as described above. These protections may result in CEG tolerating greater risks when making decisions than otherwise might be the case, including when determining whether to use leverage in connection with acquisitions. The indemnification arrangements to which CEG is a party may also give rise to legal claims for indemnification that are adverse to the Company and its unit holders.
Certain of the Company’s PPAs and project-level financing arrangements include provisions that would permit the counterparty to terminate the contract or accelerate maturity in the event GIP or its affiliates ceases to control or own, directly or indirectly, a majority of the voting power of the Company.
Certain of the Company’s PPAs and project-level financing arrangements contain change in control provisions that provide the counterparty with a termination right or the ability to accelerate maturity in the event of a change of control of the Company without the counterparty's consent. These provisions are triggered in the event GIP or its affiliates ceases to own, directly or indirectly, capital stock representing more than 50% of the voting power of the Company’s capital stock outstanding on such date, or, in some cases, if GIP or its affiliates ceases to be the majority owner, directly or indirectly, of the applicable project subsidiary. As a result, if GIP or its affiliates ceases to control, or in some cases, own a majority of the voting power of the Company, the counterparties could terminate such contracts or accelerate the maturity of such financing arrangements. The termination of any of the Company’s PPAs or the acceleration of the maturity of any of the Company’s project-level financing could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flow.
Risks Related to Regulation
•The Company’s business is subject to restrictions resulting from environmental, health and safety laws and regulations.
•The electric generation business is subject to substantial governmental regulation, including environmental laws, and may be adversely affected by changes in laws or regulations, as well as liability under, or any future inability to comply with, existing or future regulations or other legal requirements.
•The Company’s business is subject to complex and evolving U.S. laws and regulations regarding privacy and data protection.
•Government regulations providing incentives for renewable power generation could change at any time and such changes may negatively impact the Company’s growth strategy.
Risks Related to the Company’s Business
Pursuant to the Company’s cash distribution policy, the Company intends to distribute a significant amount of the CAFD through regular quarterly distributions, and the Company’s ability to grow and make acquisitions through cash on hand is limited.
The Company expects to distribute a significant amount of the CAFD each quarter and to rely primarily upon external financing sources, including the issuance of debt and equity securities and, if applicable, borrowings under the Company’s revolving credit facility to fund acquisitions and growth capital expenditures. The Company may be precluded from pursuing otherwise attractive acquisitions if the projected short-term cash flow from the acquisition or investment is not adequate to service the capital raised to fund the acquisition or investment, after giving effect to the Company’s available cash reserves. The incurrence of bank borrowings or other debt by Clearway Energy Operating LLC or by the Company’s project-level subsidiaries to finance the Company’s growth strategy will result in increased interest expense and the imposition of additional or more restrictive covenants, which, in turn, may impact the cash distributions the Company makes to Clearway, Inc. and CEG.
The Company may not be able to effectively identify or consummate any future acquisitions on favorable terms, or at all, and future acquisitions may not be accretive as a result of incorrect assumptions in the Company’s evaluation of such acquisitions, unforeseen consequences or other external events beyond the Company’s control.
The Company’s business strategy includes growth through the acquisitions of additional generation assets (including through corporate acquisitions). This strategy depends on the Company’s ability to successfully identify and evaluate acquisition opportunities and consummate acquisitions on favorable terms. However, the number of acquisition opportunities is limited. In addition, the Company will compete with other companies for these limited acquisition opportunities, which may increase the Company’s cost of making acquisitions or cause the Company to refrain from making acquisitions at all. Some of the Company’s competitors for acquisitions are much larger than the Company with substantially greater resources. These companies may be able to pay more for acquisitions and may be able to identify, evaluate, bid for and purchase a greater number of assets than the Company’s financial or human resources permit. If the Company is unable to identify and consummate future acquisitions, it will impede the Company’s ability to execute its growth strategy and limit the Company’s ability to increase the amount of distributions paid to holders of Clearway, Inc.’s common stock.
The Company’s ability to acquire future renewable facilities may depend on the viability of renewable assets generally. These assets currently are largely contingent on public policy mechanisms including ITCs, cash grants, loan guarantees, accelerated depreciation, RPS and carbon trading plans. These mechanisms have been implemented at the state and federal levels to support the development of renewable generation, demand-side and smart grid and other clean infrastructure technologies. The availability and continuation of public policy support mechanisms will drive a significant part of the economics and viability of the Company’s growth strategy and expansion into clean energy investments.
The acquisition of companies and assets are subject to substantial risks, including the failure to identify material problems during due diligence (for which the Company may not be indemnified post-closing) and the risk of overpaying for assets (or not making acquisitions on an accretive basis). The integration and consolidation of acquisitions requires substantial human, financial and other resources and, ultimately, the Company’s acquisitions may divert management’s attention from the Company’s existing business concerns, disrupt the Company’s ongoing business or not be successfully integrated. There can be no assurances that any future acquisitions will perform as expected or that the returns from such acquisitions will support the financing utilized to acquire them or maintain them. A failure to achieve the financial returns the Company expects when it acquires generation assets could have a material adverse effect on the Company’s ability to grow its business and make cash distributions to its unit holders. Any failure of the Company’s acquired generation assets to be accretive or difficulty in integrating such acquisition into the Company’s business could have a material adverse effect on the Company’s ability to grow its business and make cash distributions to its unit holders. As a result, the consummation of acquisitions could have a material adverse effect on the Company’s business, financial condition, results of operations, cash flows and ability to pay distributions to its unit holders.
Counterparties to the Company’s offtake agreements may not fulfill their obligations and, as the contracts expire, the Company may not be able to replace them with agreements on similar terms in light of increasing competition in the markets in which the Company operates.
A significant portion of the electric power the Company generates is sold under long-term offtake agreements with public utilities or industrial or commercial end-users, with a weighted average remaining duration, based on CAFD, of approximately 11 years. As of December 31, 2022, the largest customers of the Company’s power generation assets, including assets in which the Company has less than a 100% membership interest, were SCE and PG&E, which represented 33% and 25%, respectively, of total consolidated revenues generated by the Company during the year ended December 31, 2022.
If, for any reason, any of the purchasers of power under these agreements are unable or unwilling to fulfill their related contractual obligations or if they refuse to accept delivery of power delivered thereunder or if they otherwise terminate such agreements prior to the expiration thereof, the Company’s assets, liabilities, business, financial condition, results of operations and cash flows could be materially and adversely affected. Furthermore, to the extent any of the Company’s power purchasers are, or are controlled by, governmental entities, the Company’s facilities may be subject to legislative or other political action that may impair their contractual performance.
The power generation industry is characterized by intense competition and the Company’s electric generation assets encounter competition from utilities, industrial companies and independent power producers, in particular with respect to uncontracted output. In recent years, there has been increasing competition among generators for offtake agreements and this has contributed to a reduction in electricity prices in certain markets characterized by excess supply above designated reserve margins. In light of these market conditions, the Company may not be able to replace an expiring or terminated agreement with an agreement on equivalent terms and conditions, including at prices that permit operation of the related facility on a profitable basis. In addition, the Company believes many of its competitors have well-established relationships with the Company’s current and potential suppliers, lenders and customers, and have extensive knowledge of its target markets. As a result, these competitors may be able to respond more quickly than the Company to evolving industry standards and changing customer requirements. The adoption of more advanced technology could reduce its competitors’ power production costs resulting in their having a lower cost structure than is achievable with the technologies currently employed by the Company and adversely affect its ability to compete for offtake agreement renewals. If the Company is unable to replace an expiring or terminated offtake agreement, the affected facility may temporarily or permanently cease operations. External events, such as a severe economic downturn or force majeure events, could also impair the ability of some counterparties to the Company’s offtake agreements and other customer agreements to pay for energy and/or other products and services received.
The Company’s inability to enter into new or replacement offtake agreements or to compete successfully against current and future competitors in the markets in which the Company operates could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flows.
The Company’s ability to effectively consummate future acquisitions will also depend on the Company’s ability to arrange the required or desired financing for acquisitions.
The Company may not have sufficient availability under the Company’s credit facilities or have access to project-level financing on commercially reasonable terms when acquisition opportunities arise. An inability to obtain the required or desired financing could significantly limit the Company’s ability to consummate future acquisitions and effectuate the Company’s growth strategy. If financing is available, utilization of the Company’s credit facilities or project-level financing for all or a portion of the purchase price of an acquisition could significantly increase the Company’s interest expense, impose additional or more restrictive covenants and reduce CAFD. The Company’s ability to consummate future acquisitions may also depend on the Company’s ability to obtain any required regulatory approvals for such acquisitions.
The Company’s indebtedness could adversely affect its ability to raise additional capital to fund the Company’s operations or pay distributions. It could also expose the Company to the risk of increased interest rates and limit the Company’s ability to react to changes in the economy or the Company’s industry as well as impact the Company’s results of operations, financial condition and cash flows.
As of December 31, 2022, the Company had approximately $6,872 million of total consolidated indebtedness, $4,745 million of which was incurred by the Company’s non-guarantor subsidiaries. In addition, the Company’s share of its unconsolidated affiliates’ total indebtedness and letters of credit outstanding as of December 31, 2022, totaled approximately $325 million and $37 million, respectively (calculated as the Company’s unconsolidated affiliates’ total indebtedness as of such date multiplied by the Company’s percentage membership interest in such assets).
The Company’s substantial debt could have important negative consequences on the Company’s financial condition, including:
•increasing the Company’s vulnerability to general economic and industry conditions;
•requiring a substantial portion of the Company’s cash flow from operations to be dedicated to the payment of principal and interest on the Company’s indebtedness, therefore reducing the Company’s ability to pay distributions to Clearway, Inc. and CEG or to use the Company’s cash flow to fund its operations, capital expenditures and future business opportunities;
•limiting the Company’s ability to enter into long-term power sales or fuel purchases which require credit support;
•limiting the Company’s ability to fund operations or future acquisitions;
•restricting the Company’s ability to make certain distributions to Clearway, Inc. and CEG and the ability of the Company’s subsidiaries to make certain distributions to it, in light of restricted payment and other financial covenants in the Company’s credit facilities and other financing agreements;
•exposing the Company to the risk of increased interest rates because certain of the Company’s borrowings, which may include borrowings under the Company’s revolving credit facility, are at variable rates of interest;
•limiting the Company’s ability to obtain additional financing for working capital including collateral postings, capital expenditures, debt service requirements, acquisitions and general corporate or other purposes; and
•limiting the Company’s ability to adjust to changing market conditions and placing it at a competitive disadvantage compared to the Company’s competitors who have less debt.
The Company’s revolving credit facility contains financial and other restrictive covenants that limit the Company’s ability to return capital to unit holders or otherwise engage in activities that may be in the Company’s long-term best interests. The Company’s inability to satisfy certain financial covenants could prevent the Company from paying cash distributions, and the Company’s failure to comply with those and other covenants could result in an event of default which, if not cured or waived, may entitle the related lenders to demand repayment or enforce their security interests, which could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flows. In addition, failure to comply with such covenants may entitle the related lenders to demand repayment and accelerate all such indebtedness.
The agreements governing the Company’s project-level financing contain financial and other restrictive covenants that limit the Company’s project subsidiaries’ ability to make distributions to the Company or otherwise engage in activities that may be in the Company’s long-term best interests. The project-level financing agreements generally prohibit distributions from the project entities to the Company unless certain specific conditions are met, including the satisfaction of certain financial ratios. The Company’s inability to satisfy certain financial covenants may prevent cash distributions by the particular project(s) to it and, the Company’s failure to comply with those and other covenants could result in an event of default which, if not cured or waived may entitle the related lenders to demand repayment or enforce their security interests, which could have a material adverse effect on the Company’s business, results of operations and financial condition. In addition, failure to comply with such covenants may entitle the related lenders to demand repayment and accelerate all such indebtedness. If the Company is unable to make distributions from the Company’s project-level subsidiaries, it would likely have a material adverse effect on the Company’s ability to pay distributions to Clearway, Inc. and CEG.
Letter of credit facilities to support project-level contractual obligations generally have a limited term that may require future renewal, at which time the Company or relevant project-level subsidiary will need to satisfy applicable financial ratios and covenants. If the Company is unable to renew the Company’s letters of credit as expected or replace them with letters of credit under different facilities on favorable terms or at all, the Company may experience a material adverse effect on its business, financial condition, results of operations and cash flows. Furthermore, such inability may constitute a default under certain project-level financing arrangements, restrict the ability of the project-level subsidiary to make distributions to it and/or reduce the amount of cash available at such subsidiary to make distributions to the Company.
In addition, the Company’s ability to arrange financing, either at the corporate level or at a non-recourse project-level subsidiary, and the costs of such capital, are dependent on numerous factors, including:
•general economic and capital market conditions;
•credit availability from banks and other financial institutions;
•investor confidence in the Company, its partners, Clearway, Inc. (as the Company’s sole managing member), or GIP and TotalEnergies, through CEG, as Clearway, Inc.’s principal stockholder (on a combined voting basis) and the regional wholesale power markets;
•the Company’s financial performance and the financial performance of the Company subsidiaries;
•the Company’s level of indebtedness and compliance with covenants in debt agreements;
•maintenance of acceptable project credit ratings or credit quality;
•cash flow; and
•provisions of tax and securities laws that may impact raising capital.
The Company may not be successful in obtaining additional capital for these or other reasons. Furthermore, the Company may be unable to refinance or replace project-level financing arrangements or other credit facilities on favorable terms or at all upon the expiration or termination thereof. The Company’s failure, or the failure of any of the Company’s projects, to obtain additional capital or enter into new or replacement financing arrangements when due may constitute a default under such existing indebtedness and may have a material adverse effect on the Company’s business, financial condition, results of operations and cash flows.
Certain of the Company’s long-term bilateral contracts result from state-mandated procurements and could be declared invalid by a court of competent jurisdiction.
A portion of the Company’s revenues are derived from long-term bilateral contracts with utilities that are regulated by their respective states and have been entered into pursuant to certain state programs. Certain long-term contracts that other companies have with state-regulated utilities have been challenged in federal court and have been declared unconstitutional on the grounds that the rate for energy and capacity established by the contracts impermissibly conflicts with the rate for energy and capacity established by FERC pursuant to the FPA. If certain of the Company’s state-mandated agreements with utilities are ever held to be invalid or unenforceable due to the financial conditions or other conditions of such utility, the Company may be unable to replace such contracts, which could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flows.
The generation of electric energy from solar and wind energy sources depends heavily on suitable meteorological conditions.
If solar or wind conditions are unfavorable, the Company’s electricity generation and revenue from renewable generation facilities may be substantially below the Company’s expectations. The electricity produced and revenues generated by a solar or wind energy generation facility is highly dependent on suitable solar or wind conditions, as applicable, and associated weather conditions, which are beyond the Company’s control. Disruption in the generation of solar or wind energy could limit a facility’s ability to generate electricity at its desired level. Should a generation facility fail to perform at the required levels, or other unplanned disruptions occur, the facility may be forced to fulfill an underlying contractual obligation by purchasing electricity at higher prices. In addition, the Company’s facilities may be exposed, based on specific contractual terms, to a locational basis risk resulting from a difference in the price received for generation sold at the location where the power is generated and the price paid for generation purchased at the contracted delivery point, which could lead to potential lower revenues in circumstances where the price received is lower than the price that is paid. Furthermore, components of the Company’s systems, such as solar panels and inverters, could be damaged by severe weather, such as wildfires, hailstorms, lightning, tornadoes or freezing temperatures and other winter weather conditions. In addition, replacement and spare parts for key components may be difficult or costly to acquire or may be unavailable. Unfavorable weather and atmospheric conditions could impair the effectiveness of the Company’s assets or reduce their output beneath their rated capacity or require shutdown of key equipment, impeding operation of the Company’s renewable assets. For example, in February 2021, the Company’s wind projects in Texas were unable to operate and experienced outages for a few days as a result of the extreme winter weather conditions. In addition, climate change may have the long-term effect of changing wind patterns at the Company’s projects. Changing wind patterns could cause changes in expected electricity generation. These events could also degrade equipment or components and the interconnection and transmission facilities’ lives or maintenance costs.
Although the Company bases its investment decisions with respect to each renewable generation facility on the findings of related wind and solar studies conducted on-site prior to construction or based on historical conditions at existing facilities, actual climatic conditions at a facility site, particularly wind conditions, may not conform to the findings of these studies and may be affected by variations in weather patterns, including any potential impact of climate change. Therefore, the Company’s solar and wind energy facilities may not meet anticipated production levels or the rated capacity of the Company’s generation assets, which could adversely affect the Company’s business, financial condition, results of operations and cash flows.
Operation of electric generation facilities involves significant risks and hazards customary to the power industry that could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flows.
The ongoing operation of the Company’s facilities involves risks that include the breakdown or failure of equipment or processes or performance below expected levels of output or efficiency due to wear and tear, latent defect, design error or operator error or force majeure events, among other things. The Company’s facilities are subject to the risks inherent with power generation facilities, including, but not limited to, degradation of equipment in excess of the Company’s expectations, system failures and outages, which could impair the ability of the facilities to meet the Company’s performance expectations. Operation of the Company’s facilities also involves risks that the Company will be unable to transport its products to its customers in an efficient manner due to a lack of transmission capacity. Unplanned outages of generating units, including extensions of scheduled outages due to mechanical failures or other problems, occur from time to time and are an inherent risk of the business. Unplanned outages typically increase operation and maintenance expenses, capital expenditures and may reduce revenues as a result of selling fewer MWh or require the Company to incur significant costs as a result of obtaining replacement power from third parties in the open market to satisfy forward power sales obligations. The Company’s inability to operate its electric generation assets efficiently, manage capital expenditures and costs and generate earnings and cash flow from the Company’s asset-based businesses could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flows. While the Company maintains insurance, obtains warranties from vendors and obligates contractors to meet certain performance levels, the proceeds of such insurance, warranties or performance guarantees may not cover the Company’s lost revenues, increased expenses or liquidated damages payments should it experience equipment breakdown or non-performance by contractors or vendors. The Company maintains an amount of insurance protection that it considers adequate but cannot provide any assurance that the Company’s insurance will be sufficient or effective under all circumstances and against all hazards or liabilities to which the Company may be subject. Furthermore, the Company’s insurance coverage is subject to deductibles, caps, exclusions and other limitations. A loss for which the Company is not fully insured (which may include a significant judgment against any facility or facility operator) could have a material adverse effect on the Company’s business, financial condition, results of operations or cash flows. Further, due to rising insurance costs and changes in the insurance markets, the Company cannot provide any assurance that its insurance coverage will continue to be available at all or at rates or on terms similar to those presently available. Any losses not covered by insurance could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flows.
Power generation involves hazardous activities, including acquiring, transporting and unloading fuel, operating large pieces of rotating equipment and delivering electricity to transmission and distribution systems. In addition to natural risks such as earthquake, flood, lightning, hurricane and wind, other hazards, such as fire, explosion, structural collapse and machinery failure are inherent risks in the Company’s operations. These and other hazards can cause significant personal injury or loss of life, severe damage to and destruction of property, plant and equipment and contamination of, or damage to, the environment and suspension of operations. To the extent an event was not covered by insurance policies, such incidents could subject the Company to substantial liabilities arising from emergency response, environmental cleanup and restoration costs, claims made by neighboring landowners and other third parties for personal injury and property damage, and fines or penalties for any related violations of environmental laws or regulations.
The Company’s facilities may operate, wholly or partially, without long-term power sales agreements.
The Company’s facilities may operate without long-term power sales agreements for some or all of their generating capacity and output and therefore be exposed to market fluctuations. Without the benefit of long-term power sales agreements for the facilities, the Company cannot be sure that it will be able to sell any or all of the power generated by the facilities at commercially attractive rates or that the facilities will be able to operate profitably. This could lead to less predictable revenues, future impairments of the Company’s property, plant and equipment or to the closing of certain of its facilities, resulting in economic losses and liabilities, which could have a material adverse effect on the Company’s results of operations, financial condition or cash flows.
Maintenance, expansion and refurbishment of electric generation facilities involve significant risks that could result in unplanned power outages or reduced output.
The Company’s facilities may require periodic upgrading and improvement. Any unexpected operational or mechanical failure, including failure associated with breakdowns and forced outages, could reduce the Company’s facilities’ generating capacity below expected levels, reducing the Company’s revenues and jeopardizing the Company’s ability to pay distributions to Clearway, Inc. and CEG at expected levels or at all. Degradation of the performance of the Company’s solar facilities above levels provided for in the related offtake agreements may also reduce the Company’s revenues. Unanticipated capital expenditures associated with maintaining, upgrading or repairing the Company’s facilities may also reduce profitability.
If the Company makes any major modifications to its conventional power generation facilities, it may be required to install the best available control technology or to achieve the lowest achievable emission rates as such terms are defined under the new source review provisions of the Clean Air Act in the future. Any such modifications could likely result in substantial additional capital expenditures. The Company may also choose to repower, refurbish or upgrade its facilities based on its assessment that such activity will provide adequate financial returns. Such facilities require time for development and capital expenditures before commencement of commercial operations, and key assumptions underpinning a decision to make such an investment may prove incorrect, including assumptions regarding construction costs, timing, available financing and future fuel and power prices. These events could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flows.
Supplier and/or customer concentration at certain of the Company’s facilities may expose the Company to significant financial credit or performance risks.
The Company often relies on a single contracted supplier or a small number of suppliers for the provision of fuel, transportation of fuel, equipment, technology and/or other services required for the operation of certain facilities. In addition, certain of the Company’s suppliers provide long-term warranties with respect to the performance of their products or services. If any of these suppliers cannot perform under their agreements with the Company, or satisfy their related warranty obligations, the Company will need to utilize the marketplace to provide or repair these products and services. There can be no assurance that the marketplace can provide these products and services as, when and where required. The Company may not be able to enter into replacement agreements on favorable terms or at all. If the Company is unable to enter into replacement agreements to provide for fuel, equipment, technology and other required services, it would seek to purchase the related goods or services at market prices, exposing the Company to market price volatility and the risk that fuel and transportation may not be available during certain periods at any price. The Company may also be required to make significant capital contributions to remove, replace or redesign equipment that cannot be supported or maintained by replacement suppliers, which could have a material adverse effect on the business, financial condition, results of operations, credit support terms and cash flows.
In addition, potential or existing customers at the Company’s district energy centers and combined heat and power plants, or the Energy Centers, may opt for on-site systems in lieu of using the Company’s Energy Centers, either due to corporate policies regarding the allocation of capital, unique situations where an on-site system might in fact prove more efficient, because of previously committed capital in systems that are already on-site, or otherwise. At times, the Company relies on a single customer or a few customers to purchase all or a significant portion of a facility’s output, in some cases under long-term agreements that account for a substantial percentage of the anticipated revenue from a given facility.
The failure of any supplier to fulfill its contractual obligations to the Company or the Company’s loss of potential or existing customers could have a material adverse effect on its financial results. Consequently, the financial performance of the Company’s facilities is dependent on the credit quality of, and continued performance by, the Company’s suppliers and vendors and the Company’s ability to solicit and retain customers.
The Company currently owns, and in the future may acquire, certain assets in which the Company has limited control over management decisions and its interests in such assets may be subject to transfer or other related restrictions.
As described in Item 15 — Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, the Company has limited control over the operation of certain of its assets, because the Company beneficially owns less than a majority of the membership interests in such assets. The Company may seek to acquire additional assets in which it owns less than a majority of the related membership interests in the future. In these investments, the Company will seek to exert a degree of influence with respect to the management and operation of assets in which it owns less than a majority of the membership interests by negotiating to obtain positions on management committees or to receive certain limited governance rights, such as rights to veto significant actions. However, the Company may not always succeed in such negotiations. The Company may be dependent on its co-venturers to operate such assets. The Company’s co-venturers may not have the level of experience, technical expertise, human resources management and other attributes necessary to operate these assets optimally. In addition, conflicts of interest may arise in the future between theCompany and its unit holders, on the one hand, and the Company’s co-venturers, on the other hand, where the Company’s co-venturers’ business interests are inconsistent with the interests of the Company and its unit holders. Further, disagreements or disputes between the Company and its co-venturers could result in litigation, which could increase expenses and potentially limit the time and effort the Company’s officers and directors are able to devote to the business.
The approval of co-venturers may also be required for the Company to receive distributions of funds from assets or to sell, pledge, transfer, assign or otherwise convey its interest in such assets, or for the Company to acquire CEG’s interests in such co-ventures as an initial matter. Alternatively, the Company’s co-venturers may have rights of first refusal or rights of first offer in the event of a proposed sale or transfer of the Company’s interests in such assets. These restrictions may limit the price or interest level for interests in such assets, in the event the Company wants to sell such interests.
Furthermore, certain of the Company’s facilities are operated by third-party operators. To the extent that third-party operators do not fulfill their obligations to manage operations of the facilities or are not effective in doing so, the amount of CAFD may be adversely affected.
The Company’s assets are exposed to risks inherent in the use of interest rate swaps and the Company may be exposed to additional risks in the future if it utilizes other derivative instruments.
The Company uses interest rate swaps to manage interest rate risk. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these contracts. If the values of these financial contracts change in a manner that the Company does not anticipate, or if a counterparty fails to perform under a contract, it could harm the business, financial condition, results of operations and cash flows.
The Company does not own all of the land on which its power generation assets are located, which could result in disruption to its operations.
The Company does not own all of the land on which its power generation assets are located, and the Company is, therefore, subject to the possibility of less desirable terms and increased costs to retain necessary land use if it does not have valid leases or rights-of-way or if such rights-of-way lapse or terminate. Although the Company has obtained rights to construct and operate these assets pursuant to related lease arrangements, the rights to conduct those activities are subject to certain exceptions, including the term of the lease arrangement. The Company is also at risk of condemnation on land it owns. The loss of these rights, through the Company’s inability to renew right-of-way contracts, condemnation or otherwise, may adversely affect the Company’s ability to operate its generation assets.
The Company’s use and enjoyment of real property rights for its projects may be adversely affected by the rights of lienholders and leaseholders that are superior to those of the grantors of those real property rights to the Company.
Solar and wind projects generally are, and are likely to be, located on land occupied by the project pursuant to long-term easements and leases. The ownership interests in the land subject to these easements and leases may be subject to mortgages securing loans or other liens (such as tax liens) and other easement and lease rights of third parties (such as leases of oil or mineral rights) that were created prior to the project’s easements and leases. As a result, the project’s rights under these easements or leases may be subject, and subordinate, to the rights of those third parties. The Company performs title searches and obtains title insurance to protect itself against these risks. Such measures may, however, be inadequate to protect the Company against all risk of loss of its rights to use the land on which the wind projects are located, which could have a material adverse effect on the Company’s business, financial condition and results of operations.
The Company’s businesses are subject to physical, market and economic risks relating to potential effects of climate change and public and governmental initiatives to address climate change.
Climate change creates uncertainty in weather and other environmental conditions, including temperature and precipitation levels, and thus may affect consumer demand for electricity. For example, deviations from normal weather may reduce demand or availability of electricity and gas distribution services. In addition, the potential physical effects of climate change, such as increased frequency and severity of storms, cloud coverage, precipitation, floods and other climatic events, could disrupt the Company’s operations and supply chain, and cause them to incur significant costs in preparing for or responding to these effects. These or other meteorological changes could lead to increased operating costs, capital expenses or power purchase costs.
Furthermore, governmental, scientific and public concern over the threat of climate change arising from GHG emissions may limit the Company’s access to natural gas or decrease demand for energy generated by the Company’s conventional assets. State, national and foreign governments and agencies continue to evaluate, and in some instances adopt, climate-related legislation and other regulatory initiatives that would restrict GHG emissions. Changes in environmental requirements related to GHG, climate change and alternative energy sources may impact demand for the Company’s services. For example, recently enacted H.R. 5376, commonly known as the Inflation Reduction Act of 2022, or IRA, includes incentives to increase wind and solar electric generation and encourage consumers to use these alternative energy sources. While this could benefit the Company by increasing the demand for the Company’s solar or wind energy, the Company could experience delayed or cancelled projects and/or reduced production and demand for energy generated by the Company’s conventional assets. However, the clean energy incentives included in the IRA or similar state or federal initiatives to incentivize a shift away from fossil fuels could reduce demand for energy generated by fossil fuels, and therefore have an adverse effect on the Company’s natural gas generation business, financial condition and results of operations.
Lastly, companies across all industries are facing increased scrutiny from the public, stakeholders and government agencies related to their environmental, social, and governance (ESG) practices and commitments to address climate change. In recent years, investor advocacy groups, institutional investors, investment funds, and other influential investors have placed increasing importance on ESG practices. Increased focus and activism related to ESG and similar matters may hinder access to capital, as investors may decide to reallocate capital or to not commit capital as a result of their assessment of a company’s ESG practices. While the Company is committed to engaging with its stakeholders on ESG practices in a proactive, holistic and integrated manner, changes in the public or stakeholder sentiment could impact the Company’s ability to fund its conventional assets or decrease the demand for the energy generated by these assets.
Risks that are beyond the Company’s control, including but not limited to acts of terrorism or related acts of war, natural disaster, pandemics(such as the COVID-19 pandemic), inflation, supply chain disruptions, hostile cyber intrusions or other catastrophic events, could have a material adverse effect on the business, financial condition, results of operations and cash flows.
The Company’s generation facilities that were acquired or those that the Company otherwise acquires or constructs and the facilities of third parties on which they rely may be targets of terrorist activities, as well as events occurring in response to or in connection with them, that could cause environmental repercussions and/or result in full or partial disruption of the facilities ability to generate, transmit, transport or distribute electricity or natural gas. Strategic targets, such as energy-related facilities, may be at greater risk of future terrorist activities than other domestic targets. Inflation, disruption in global and domestic supply chains, and other economic conditions could negatively impact the Company’s business in a manner that could adversely affect the Company’s results of operations and financial condition. Hostile cyber intrusions, including those targeting information systems as well as electronic control systems used at the generating plants and for the related distribution systems, could severely disrupt business operations and result in loss of service to customers, as well as create significant expense to repair security breaches or system damage.
Furthermore, certain of the Company’s power generation assets are located in active earthquake zones in California and Arizona, and certain project companies and suppliers conduct their operations in the same region or in other locations that are susceptible to natural disasters. In addition, California and some of the locations where certain suppliers are located, from time to time, have experienced shortages of water, electric power and natural gas. Catastrophic events, such as an earthquake, wildfire, drought, flood, pandemics (such as the COVID-19 pandemic) or localized extended outages of critical utilities or transportation systems, or any critical resource shortages, affecting the Company or its suppliers, could cause a significant interruption in the business, damage or destroy the Company’s facilities or those of its suppliers or the manufacturing equipment or inventory of the Company’s suppliers. The Company has a limited number of highly skilled employees for some of its operations and relies on certain independent contractors and other service providers. If a large proportion of the Company’s employees in those critical positions, or independent contractors or other service providers to the Company or its customers were to be negatively impacted by a catastrophic event at the same time, the Company would rely upon its business continuity plans in an effort to continue operations at its facilities, but there is no certainty that such measures will be sufficient to mitigate the adverse impact to its operations that could result from shortages of highly skilled employees, independent contractors or service providers. Any such terrorist acts, environmental repercussions or disruptions or natural disasters could result in a significant decrease in revenues or significant reconstruction or remediation costs, beyond what could be recovered through insurance policies, which could have a material adverse effect on the business, financial condition, results of operations and cash flows.
The operation of the Company’s businesses is subject to cyber-based security and integrity risk.
Numerous functions affecting the efficient operation of the Company’s businesses depend on the secure and reliable storage, processing and communication of electronic data and the use of sophisticated computer hardware and software systems. The operation of the Company’s generating assets relies on cyber-based technologies and has been the target of disruptive actions. In addition, our business is dependent upon the computer systems of third-party providers to process certain data necessary to conduct our business, including sensitive employee information, credit card transaction information and other sensitive data.
Potential disruptive actions could result from cyber-attack or cyber intrusion, including by computer hackers, foreign governments and cyber terrorists, or otherwise be compromised by unintentional events with respect to the Company or any of its contractors or customers. As a result, operations could be interrupted, property could be damaged and sensitive employee, customer or supplier information could be lost or stolen, causing the Company to incur significant losses of revenues, other substantial liabilities and damages, costs to replace or repair damaged equipment and damage to the Company’s reputation. Our insurance may not fully protect us against such losses. In addition, the Company may experience increased capital and operating costs to implement increased security for its cyber systems and generating assets.
In addition, cyberattacks against us or others in our industry could result in additional regulations, which could lead to increased regulatory compliance costs, insurance coverage cost or capital expenditures. Any failure by us to comply with these additional regulations could result in significant penalties and liability to us. We cannot predict the potential impact to our business or the energy industry resulting from such additional regulations.
The Company relies on electric distribution and transmission facilities that it does not own or control and that are subject to transmission constraints within a number of the Company’s regions. If these facilities fail to provide the Company with adequate transmission capacity, it may be restricted in its ability to deliver electric power to its customers and may either incur additional costs or forego revenues.
The Company depends on electric distribution and transmission facilities owned and operated by others to deliver the wholesale power it will sell from its electric generation assets to its customers. A failure or delay in the operation or development of these facilities or a significant increase in the cost of the development of such facilities could result in lost revenues. Such failures or delays could limit the amount of power the Company’s operating facilities deliver or delay the completion of the Company’s construction projects. Additionally, such failures, delays or increased costs could have a material adverse effect on the business, financial condition and results of operations. If a region’s power transmission infrastructure is inadequate, the Company’s recovery of wholesale costs and profits may be limited. If restrictive transmission price regulation is imposed, the transmission companies may not have a sufficient incentive to invest in expansion of transmission infrastructure. The Company also cannot predict whether distribution or transmission facilities will be expanded in specific markets to accommodate competitive access to those markets. In addition, certain of the Company’s operating facilities’ generation of electricity may be curtailed without compensation due to transmission limitations or limitations on the electricity grid’s ability to accommodate intermittent and other electricity generating sources, reducing the Company’s revenues and impairing its ability to capitalize fully on a particular facility’s generating potential. Such curtailments could have a material adverse effect on the business, financial condition, results of operations and cash flows. Furthermore, economic congestion on transmission networks in certain of the markets in which the Company operates may occur and the Company may be deemed responsible for congestion costs. If the Company were liable for such congestion costs, its financial results could be adversely affected.
The Company’s costs, results of operations, financial condition and cash flows could be adversely impacted by the disruption of the fuel supplies necessary to generate power at its conventional power generation facilities.
Delivery of fossil fuels to fuel the Company’s conventional generation facilities is dependent upon the infrastructure (including natural gas pipelines) available to serve each such generation facility as well as upon the continuing financial viability of contractual counterparties. As a result, the Company is subject to the risks of disruptions or curtailments in the production of power at these generation facilities if a counterparty fails to perform or if there is a disruption in the fuel delivery infrastructure.
The Company depends on key personnel and its ability to attract and retain additional skilled management and other personnel, the loss of any of which could have a material adverse effect on the Company’s financial condition and results of operations.
The Company believes its current operations and future success depend largely on the continued services of key personnel that it employs. Although the Company currently has access to the resources of CEG, the loss of key personnel employed by the Company or CEG could have a material adverse effect on the Company’s financial condition and results of operations.
The Company may potentially be adversely affected by emerging technologies that may over time impact capacity markets and the energy industry overall.
Research and development activities are ongoing in the Company’s industry to provide alternative and more efficient technologies to produce power, including wind, photovoltaic (solar) cells, hydrogen, energy storage, and improvements in traditional technologies and equipment, such as more efficient gas turbines. Advances in these or other technologies could reduce the costs of power production to a level below what the Company has currently forecasted, which could adversely affect its cash flows, results of operations or competitive position.
Some emerging technologies, such as distributed renewable energy technologies, broad consumer adoption of electric vehicles and energy storage devices, could affect the price of energy. These emerging technologies may affect the financial viability of utility counterparties and could have significant impacts on market prices, which could ultimately have a material adverse effect on the Company’s financial condition, results of operations and cash flows.
Risks Related to the Company’s Relationships with GIP, TotalEnergies and CEG
GIP and TotalEnergies, through their equal ownership of CEG, exercise substantial influence over the Company through CEG’s position as controlling shareholder of Clearway, Inc. The Company is highly dependent on GIP, TotalEnergies and CEG.
CEG owns all of Clearway, Inc.’s outstanding Class B and Class D common stock. Clearway, Inc.’s outstanding Class B and Class D common stock is entitled to one vote per share and 1/100th of a vote per share, respectively. As a result of its ownership of Clearway, Inc.’s Class B and Class D common stock, CEG owns 54.91% of the combined voting power of Clearway, Inc.’s common stock as of December 31, 2022. CEG is equally owned by GIP and TotalEnergies. Clearway, Inc., through its holdings of Class A units and Class C units, owned a 57.88% economic interest in the Company as of December 31, 2022. Additionally, GIP and TotalEnergies, through CEG’s holdings of Class B units and Class D units, owned the remaining 42.12% economic interest in the Company as of December 31, 2022. As a result of this ownership, GIP and TotalEnergies have a substantial influence on the Company’s affairs.
Furthermore, the Company depends on certain services provided by or under the direction of CEG under the CEG Master Services Agreement, including numerous processes related to the Company’s internal control over financial reporting. CEG personnel and support staff that provide services to the Company under the CEG Master Services Agreement are not required to, and the Company does not expect that they will, have as their primary responsibility the management and administration of the Company or to act exclusively for the Company and the CEG Master Services Agreement does not require any specific individuals to be provided by CEG. Under the CEG Master Services Agreement, CEG has the discretion to determine which of its employees perform assignments required to be provided to the Company. Any failure to effectively manage the Company’s processes related to internal controls over financial reporting, operations or to implement its strategy could have a material adverse effect on the business, financial condition, results of operations and cash flows. The CEG Master Services Agreement will continue in perpetuity, until terminated in accordance with its terms.
The Company also depends upon CEG and third parties for the provision of management, administration, O&M and certain other services at certain of the Company’s facilities. Any failure by CEG or third parties to perform its requirements under these arrangements or the failure by the Company to identify and contract with replacement service providers, if required, could adversely affect the operation of the Company’s facilities and have a material adverse effect on the business, financial condition, results of operations and cash flows.
CEG controls the Company and has the ability to designate a majority of the members of Clearway, Inc.’s Board.
Due to CEG’s approximate 54.91% combined voting power in Clearway, Inc., the ability of other holders of Clearway, Inc.’s Class A and Class C common stock to exercise control over the corporate governance of the Company is limited. GIP and TotalEnergies, through their equal ownership of CEG, have a substantial influence on Clearway, Inc.’s affairs, and CEG’s voting power constitutes a large percentage of any quorum of Clearway, Inc.’s stockholders voting on any matter requiring the approval of Clearway, Inc.’s stockholders. Such matters include the election of directors, the adoption of amendments to Clearway, Inc.’s amended and restated certificate of incorporation and fourth amended and restated bylaws and approval of mergers or sale of all or substantially all of its assets. This concentration of ownership may also have the effect of delaying or preventing a change in control of Clearway, Inc. or discouraging others from making tender offers for Clearway, Inc.’s shares. In addition, GIP, TotalEnergies and their respective affiliates have the right to elect all of Clearway, Inc.’s directors. It is possible that the interests of GIP, TotalEnergies and their respective affiliates may in certain circumstances differ from the interests of the Company or other holders of Clearway, Inc.’s Class A and Class C common stock.
The Company may not be able to consummate future acquisitions from CEG.
The Company’s ability to grow through acquisitions depends, in part, on CEG’s ability to identify and present the Company with acquisition opportunities. Although CEG has agreed, pursuant to the CEG ROFO Agreement, to grant the Company a right of first offer with respect to certain power generation assets that CEG may elect to sell in the future, CEG is under no obligation to sell any such power generation assets or to accept any related offers from the Company. In addition, CEG has not agreed to commit any minimum level of dedicated resources for the pursuit of renewable power-related acquisitions. There are a number of factors which could materially and adversely impact the extent to which suitable acquisition opportunities are made available from CEG, including that the same professionals within CEG’s organization that are involved in acquisitions that are suitable for the Company have responsibilities within CEG’s broader asset management business, which may include sourcing acquisition opportunities for CEG. Limits on the availability of such individuals will likewise result in a limitation on the availability of acquisition opportunities for the Company. In making these determinations, CEG may be influenced by factors that result in a misalignment with the Company’s interests or conflict of interest.
The Company may be unable to terminate the CEG Master Services Agreement, in certain circumstances.
The CEG Master Services Agreement provides that the Company may terminate the agreement upon 30 days prior written notice to CEG upon the occurrence of any of the following: (i) CEG defaults in the performance or observance of any material term, condition or covenant contained therein in a manner that results in material harm to the Company and the default continues unremedied for a period of 30 days after written notice thereof is given to CEG; (ii) CEG engages in any act of fraud, misappropriation of funds or embezzlement that results in material harm to the Company; (iii) CEG is grossly negligent in the performance of its duties under the agreement and such negligence results in material harm to the Company; or (iv) upon the happening of certain events relating to the bankruptcy or insolvency of CEG. Furthermore, if the Company requests an amendment to the scope of services provided by CEG under the CEG Master Services Agreement and is not able to agree with CEG as to a change to the service fee resulting from a change in the scope of services within 180 days of the request, the Company will be able to terminate the agreement upon 30 days prior notice to CEG. The Company will not be able to terminate the agreement for any other reason, including if CEG experiences a change of control, and the agreement continues in perpetuity, until terminated in accordance with its terms. If CEG’s performance does not meet the expectations of investors, and the Company is unable to terminate the CEG Master Services Agreement, the market price of the Class A and Class C common stock could suffer.
If CEG terminates the CEG Master Services Agreement or defaults in the performance of its obligations under the agreement, the Company may be unable to contract with a substitute service provider on similar terms, or at all.
The Company relies on CEG to provide certain services under the CEG Master Services Agreement. The CEG Master Services Agreement provides that CEG may terminate the agreement upon 180 days prior written notice of termination to the Company if the Company defaults in the performance or observance of any material term, condition or covenant contained in the agreement in a manner that results in material harm and the default continues unremedied for a period of 30 days after written notice of the breach is given. If CEG terminates the Management Services Agreement or defaults in the performance of its obligations under the agreement, the Company may be unable to contract with CEG or a substitute service provider on similar terms or at all, and the costs of substituting service providers may be substantial. In addition, in light of CEG’s familiarity with the Company’s assets, a substitute service provider may not be able to provide the same level of service due to lack of pre-existing synergies.
The liability of CEG is limited under the Company’s arrangements with it and the Company has agreed to indemnify CEG against claims that it may face in connection with such arrangements, which may lead CEG to assume greater risks when making decisions relating to the Company than it otherwise might if acting solely for its own account.
Under the CEG Master Services Agreement, CEG does not assume any responsibility other than to provide or arrange for the provision of the services described in the CEG Master Services Agreement in good faith. In addition, under the CEG Master Services Agreement, the liability of CEG and its affiliates is limited to the fullest extent permitted by law to conduct involving bad faith, fraud, willful misconduct or gross negligence or, in the case of a criminal matter, action that was known to have been unlawful. In addition, the Company has agreed to indemnify CEG to the fullest extent permitted by law from and against any claims, liabilities, losses, damages, costs or expenses incurred by an indemnified person or threatened in connection with the Company’s operations, investments and activities or in respect of or arising from the CEG Master Services Agreement or the services provided by CEG, except to the extent that the claims, liabilities, losses, damages, costs or expenses are determined to have resulted from the conduct in respect of which such persons have liability as described above. These protections may result in CEG tolerating greater risks when making decisions than otherwise might be the case, including when determining whether to use leverage in connection with acquisitions. The indemnification arrangements to which CEG is a party may also give rise to legal claims for indemnification that are adverse to the Company and its unit holders.
Certain of the Company’s PPAs and project-level financing arrangements include provisions that would permit the counterparty to terminate the contract or accelerate maturity in the event GIP, TotalEnergies or their respective affiliates cease to control or own, directly or indirectly, a majority of the voting power of the Company.
Certain of the Company’s PPAs and project-level financing arrangements contain change in control provisions that provide the counterparty with a termination right or the ability to accelerate maturity in the event of a change of control of the Company without the counterparty’s consent. These provisions are triggered in the event GIP, TotalEnergies or their respective affiliates cease to own, directly or indirectly, capital stock representing more than 50% of the voting power of the Company’s capital stock outstanding on such date, or, in some cases, if GIP, TotalEnergies or their respective affiliates cease to be the majority owner, directly or indirectly, of the applicable project subsidiary. As a result, if GIP, TotalEnergies or their respective affiliates cease to control, or in some cases, own a majority of the voting power of the Company, the counterparties could terminate such contracts or accelerate the maturity of such financing arrangements. The termination of any of the Company’s PPAs or the acceleration of the maturity of any of the Company’s project-level financing could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flow.
Risks Related to Regulation
The Company'sCompany’s business is subject to restrictions resulting from environmental, health and safety laws and regulations.
The Company is subject to various federal, state and local environmental and health and safety laws and regulations. In addition, the Company may be held primarily or jointly and severally liable for costs relating to the investigation and clean-up of any property where there has been a release or threatened release of a hazardous regulated material as well as other affected properties, regardless of whether the Company knew of or caused the release. In addition to these costs, which are typically not limited by law or regulation and could exceed an affected property'sproperty’s value, the Company could be liable for certain other costs, including governmental fines and injuries to persons, property or natural resources. Further, some environmental laws provide for the creation of a lien on a contaminated site in favor of the government as security for damages and any costs the government incurs in connection with such contamination and associated clean-up. Although the Company generally requires its operators to undertake to indemnify it for environmental liabilities they cause, the amount of such liabilities could exceed the financial ability of the operator to indemnify the Company. The presence of contamination or the failure to remediate contamination may adversely affect the Company'sCompany’s ability to operate the business.
Greenhouse gas (GHG) regulation could also increase the cost of electricity generated by fossil fuels, and such increases could reduce demand for the power the Company'sCompany’s conventional assets generate and market. Legislative and regulatory measures to address climate change and GHG emissions are in various phases of discussion or implementation. The EPA regulates GHG emissions from new and modified facilities that are potential major sources of criteria pollutants under the Clean Air Act'sAct’s Prevention of Significant Deterioration and Title V programs and has adopted regulations that require, among other things, preconstruction and operating permits for certain large stationary sources and the monitoring and reporting of GHGs from certain onshore oil and natural gas production sources on an annual basis.
The United States Environmental Protection Agency has proposed strict new methane emissions regulations for certain oil and gas facilities. The IRA establishes a charge on methane emissions above certain limits from the same facilities.In addition, in 2015, the U.S., Canada and the U.K. participated in the United Nations Conference on Climate Change, which led to the creation of the Paris Agreement. The Paris Agreement, which was signed by the U.S. in April 2016, requires countries to review and “represent a progression” in their intended nationally determined contributions (which set GHG emission reduction goals) every five years beginning in 2020. In November 2020, the U.S. officially withdrew from the Paris Agreement in November 2020. However, on January 20, 2021, President Biden signed an “Acceptance on Behalf of the United States of America” that will allow the U.S. to rejoin the Paris Agreement. The newly signed acceptance, deposited with the United Nations on January 20, reverses the prior withdrawal. The U.S. officially rejoined the Paris Agreement on February 19, 2021.
The U.S. Congress, along with federal and state agencies, has also considered measures to reduce the emissions of GHGs. Legislation or regulation that restricts carbon emissions could increase the cost of environmental compliance for the Company’s conventional assets by requiring the Company to install new equipment to reduce emissions from larger facilities and/or purchase emission allowances. Climate change and GHG legislation or regulation could also delay or otherwise negatively affect efforts to obtain and maintain permits and other regulatory approvals for the Company’s conventional assets’ existing and new facilities, impose additional monitoring and reporting requirements or adversely affect demand for the natural gas the Company gathers, transports and stores. Conversely, legislation or regulation that sets a price on or otherwise restricts carbon emissions could also benefit the Company by increasing demand for solar or wind energy sources. In addition, governmental, scientific and public concern over the threat of climate change arising from GHG emissions has resulted in increasing political risks in the U.S, including climate change related pledges made by the Biden Administration. Shortly after taking office in January 2021, President Biden issued a series of executive orders designed to address climate change and suspend, revise, or rescind, prior agency actions that are identified as conflicting with the Biden Administration’s climate policies. Furthermore, as part of rejoining the Paris Agreement, President Biden announced that the United States would commit to a 50 to 52 percent reduction from 2005 levels of GHG emissions by 2030 and set the goal of reaching net-zero GHG emissions by 2050. Reentry into the Paris Agreement and President Biden'sBiden’s executive orders may result in the development of additional regulations or changes to existing regulations. The effect on the Company of any new legislative or regulatory measures will depend on the particular provisions that are ultimately adopted.
The electric generation business is subject to substantial governmental regulation and may be adversely affected by changes in laws or regulations, as well as liability under, or any future inability to comply with, existing or future regulations or other legal requirements.
The Company'sCompany’s electric generation business is subject to extensive U.S. federal, state and local laws and regulations. Compliance with the requirements under these various regulatory regimes may cause the Company to incur significant additional costs, and failure to comply with such requirements could result in the shutdown of the non-complying facility, the imposition of liens, fines, and/or civil or criminal liability. Public utilities under the FPA are required to obtain FERC acceptance of their rate schedules for wholesale sales of electric energy, capacity and ancillary services. Except for generating facilities located in Hawaii or in Texas within the footprint of ERCOT, or in Puerto Rico, all of the Company’s generating companies are public utilities under the FPA with market-based rate authority unless exempt from FPA public utility rate regulation. FERC'sFERC’s orders that grant market-based rate authority to wholesale power sellers reserve the right to revoke or revise that authority if FERC subsequently determines that the seller can exercise market power in transmission or generation, create barriers to entry, or engage in abusive affiliate transactions. In addition, public utilities are subject to FERC reporting requirements that impose administrative burdens and that, if violated, can expose the company to criminal and civil penalties or other risks.
The Company'sCompany’s market-based sales are subject to certain rules prohibiting manipulative or deceptive conduct, and if any of the Company'sCompany’s generating companies with market-based rate authority are deemed to have violated those rules, they could be subject to potential disgorgement of profits associated with the violation, penalties, suspension or revocation of market basedmarket-based rate authority. If such generating companies were to lose their market-based rate authority, such companies would be required to obtain FERC'sFERC’s acceptance of a cost-of-service rate schedule and could become subject to the significant accounting, record-keeping, and reporting requirements that are imposed on utilities with cost-based rate schedules. This could have a material adverse effect on the rates the Company is able to charge for power from its facilities.
All of the Company'sCompany’s generating assets are operating either as EWGs or FUCOs as defined under the PUHCA, or as QFs as defined under the PURPA, as amended, and therefore are exempt from certain regulation under the PUHCA and the FPA. If a facility fails to maintain its status as an EWG FUCO, or a QF or there are legislative or regulatory changes revoking or limiting the exemptions to the PUHCA and/or the FPA, then the Company may be subject to significant accounting, record-keeping, access to books and records and reporting requirements, and failure to comply with such requirements could result in the imposition of penalties and additional compliance obligations.
Substantially all of the Company'sCompany’s generation assets are also subject to the reliability standards promulgated by the designated Electric Reliability Organization (currently the North American Electric Reliability Corporation, or NERC) and approved by FERC. If the Company fails to comply with the mandatory reliability standards, it could be subject to sanctions, including substantial monetary penalties and increased compliance obligations. The Company will also be affected by legislative and regulatory changes, as well as changes to market design, market rules, tariffs, cost allocations and bidding rules that occur in the existing regional markets operated by RTOs or ISOs, such as PJM. The RTOs/ISOs that oversee most of the wholesale power markets impose, and in the future may continue to impose, mitigation, including price limitations, offer caps, non-performance penalties and other mechanisms to address some of the volatility and the potential exercise of market power in these markets. These types of price limitations and other regulatory mechanisms may have a material adverse effect on the profitability of the Company'sCompany’s generation facilities acquired in the future that sell energy, capacity and ancillary products into the wholesale power markets. The regulatory environment for electric generation has undergone significant changes in the last several years due to state and federal policies affecting wholesale competition and the creation of incentives for the addition of large amounts of new renewable generation and, in some cases, transmission assets. These changes are ongoing, and the Company cannot predict the future design of the wholesale power markets or the ultimate effect that the changing regulatory environment will have on the Company'sCompany’s business. In addition, in some of these markets, interested parties have proposed to re-regulate the markets or require divestiture of electric generation assets by asset owners or operators to reduce their market share. Other proposals to re-regulate may be made and legislative or other attention to the electric power market restructuring process may delay or reverse the deregulation process. If competitive restructuring of the electric power markets is reversed, discontinued, or delayed, the Company'sCompany’s business prospects and financial results could be negatively impacted.
The Company is subject to environmental laws and regulations that impose extensive and increasingly stringent requirements on its operations, as well as potentially substantial liabilities arising out of environmental contamination.
The Company'sCompany’s assets are subject to numerous and significant federal, state and local laws, including statutes, regulations, guidelines, policies, directives and other requirements governing or relating to, among other things: protection of wildlife, including threatened and endangered species; air emissions; discharges into water; water use; the storage, handling, use, transportation and distribution of dangerous goods and hazardous, residual and other regulated materials, such as chemicals; the prevention of releases of hazardous materials into the environment; the prevention, presence and remediation of hazardous materials in soil and groundwater, both on and offsite; land use and zoning matters; and workers'workers’ health and safety matters. The Company'sCompany’s facilities could experience incidents, malfunctions and other unplanned events that could result in spills or emissions in excess of permitted levels and result in personal injury, penalties and property damage. Any failure to comply with applicable environmental laws and regulations, including those relating to equipment failures, or obtain required governmental approvals and permits, may result in the assessment of administrative, civil or criminal penalties, imposition of investigatory or remedial activities and, in certain, less common circumstances, issuance of temporary or permanent injunctions, or construction or operation bans or delays. As such, the operation of the Company'sCompany’s facilities carries an inherent risk of environmental, health and safety liabilities (including potential civil actions, compliance or remediation orders, fines and other penalties), and may result in the assets being involved from time to time in administrative and judicial proceedings relating to such matters. The Company has implemented environmental, health and safety management programs designed to continually improve environmental, health and safety performance. Environmental laws and regulations have generally become more stringent over time. Significant costs may be incurred for capital expenditures under environmental programs to keep the assets compliant with such environmental laws and regulations. If it is not economical to make those expenditures, it may be necessary to retire or mothball facilities or restrict or modify the Company'sCompany’s operations to comply with more stringent standards. These environmental requirements and liabilities could have a material adverse effect on the business, financial condition, results of operations and cash flows.
The Company'sCompany’s business is subject to complex and evolving U.S. laws and regulations regarding privacy and data protection (“data protection laws”). Many of these laws and regulations are subject to change and uncertain interpretation, and could result in claims, increased cost of operations, or otherwise harm the Company'sCompany’s business.
The regulatory environment surrounding data privacy and protection is constantly evolving and can be subject to significant change. New data protection laws pose increasingly complex compliance challenges and potentially elevate the Company'sCompany’s costs. Complying with varying jurisdictional requirements could increase the costs and complexity of compliance, and violations of applicable data protection laws can result in significant penalties. Any failure, or perceived failure, by the Company to comply with applicable data protection laws could result in proceedings or actions against the Company by governmental entities or others, subject the Company to significant fines, penalties, judgments, and negative publicity, require the Company to change its business practices, increase the costs and complexity of compliance, and adversely affect the Company'sCompany’s business. As noted above, the Company is also subject to the possibility of cyberattacks, which themselves may result in a violation of these laws. Additionally, if the Company acquires a company that has violated or is not in compliance with applicable data protection laws, the Company may incur significant liabilities and penalties as a result.
Government regulations providing incentives for renewable power generation could change at any time and such changes may negatively impact the Company'sCompany’s growth strategy.
The Company'sCompany’s growth strategy depends in part on government policies that support renewable generation and energy storage and enhance the economic viability of owning electricrenewable power generation assets. Renewable power generation assets currently benefit from various federal, state and local governmental incentives such as ITCs, cash grants in lieu of ITCs, PTCs, loan guarantees,guarantee programs, RPS, programs modifiedand accelerated cost-recovery system of depreciation and bonus depreciation.for tax purposes. These laws, regulations and policies have had a significant impact on the development of renewable energypower generation projects and they could be changed, reduced or eliminated at any time. These incentives make the development of renewable power generation projects more competitive by providing tax credits or grants and accelerated depreciation for a portion of the development costs, decreasing the costs and risks associated with developing such projects or creating demand for renewable energypower assets through RPS programs.
The elimination of,or loss of, or reduction in, such incentives could (i) decrease the attractiveness of renewable power generation projects to developers, including, but not limited to, CEG, which could reduce the Company'sCompany’s acquisition opportunities. Such an elimination, loss or reduction could alsoopportunities, (ii) reduce the Company'sCompany’s willingness to pursue or develop certain renewable energypower projects due to higher operating costs or decreased revenues under its PPAs.
If these laws, regulations and policies are not continued or renewed,PPAs, (iii) cause the market for future renewable energy PPAs mayto be smaller and the prices for future renewable energy PPAs mayto be lower. If the IRS issues guidance that limits the availability of the PTC lower and/or the ITC, the projects could generate reduced revenues and reduced economic returns, experience(iv) result in increased financing costs and encounter difficulty in obtaining financing on acceptable terms.
If the Company is unable to utilize various federal, state and local government incentives to acquire additional renewable assets in the future, or the terms of such incentives are revised in a manner that is less favorable to the Company, it may suffer a material adverse effect on the business, financial condition, results of operations and cash flows.
Many states have adopted RPS programs mandating that a specified percentage of electricity sales come from eligible sources of renewable energy. However, the regulations that govern the RPS programs, including pricing incentives for renewable energy, or reasonableness guidelines for pricing that increase valuation compared to conventional power (such as a projected value for carbon reduction or consideration of avoided integration costs), may change. If the RPS requirements are reduced or eliminated, it could lead to fewer future commodity contracts or lead to lower prices for the sale of power in future commodity contracts, which could have a material adverse effect on the Company's future growth prospects. Such material adverse effects may result from decreased revenues, reduced economic returns on certain project company investments, increased financing costs, and/or difficulty obtaining financing. Furthermore, the American Recovery and Reinvestment Act of 2009 included incentives to encourage investment in the renewable energy sector, such as cash grants in lieu of ITCs, bonus depreciation and expansion of the U.S. DOE loan guarantee program. It is uncertain what loan guarantees may be made by the U.S. DOE loan guarantee program in the future.
Any of the foregoing could have a material adverse effect on the Company'sCompany’s business, financial condition, results of operations and ability to grow its business and make cash distributions.
A portion of the steam and chilled water produced by the Company's thermal assets is sold at regulated rates, and the revenueRevenue earned by the Company'sCompany’s GenConn assets is established each year in a rate case; accordingly, the profitability of these assets is dependent on regulatory approval.
Approximately 433 net MWt of capacity from certain of the Company's thermal assets are sold at rates approved by one or more federal or state regulatory commissions, including the Pennsylvania Public Utility Commission and the California Public Utilities Commission for the thermal assets. Similarly, the revenuesRevenues related to the GenConn assets are established each year by the Connecticut Public Utilities Regulatory Authority. While such regulatory oversight is generally premised on the recovery of prudently incurred costs and a reasonable rate of return on invested capital, the rates that the Company may charge, or the revenue that the Company may earn with respect to this capacity are subject to authorization of the applicable regulatory authorities. There can be no assurance that such regulatory authorities will consider all of the costs to have been prudently incurred or that the regulatory process by which rates or revenues are determined will always result in rates or revenues that achieve full recovery of costs or an adequate return on the Company'sCompany’s capital investments. While the Company'sCompany’s rates and revenues are generally established based on an analysis of costs incurred in a base year, the rates the Company is allowed to charge, and the revenues the Company is authorized to earn, may or may not match the costs at any given time. If the Company'sCompany’s costs are not adequately recovered through these regulatory processes, it could have a material adverse effect on the business, financial condition, results of operations and cash flows.
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION
This Annual Report on Form 10-K of Clearway Energy LLC, together with its consolidated subsidiaries, or the Company, includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, or the Securities Act, and Section 21E of the Securities Exchange Act of 1934, as amended, or the Exchange Act. The words "believes," "projects," "anticipates," "plans," "expects," "intends," "estimates"“believes,” “projects,” “anticipates,” “plans,” “expects,” “intends,” “estimates” and similar expressions are intended to identify forward-looking statements. These forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause the Company'sCompany’s actual results, performance and achievements, or industry results, to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. These factors, risks and uncertainties include the factors described under Item 1A — Risk Factors and the following:
•The Company'sCompany’s ability to maintain and grow its quarterly distributions;
•Potential risks related to COVID-19 (including any variant of the virus) or any other pandemic;
•Potential risks related to the Company'sCompany’s relationships with GIP, TotalEnergies and CEG;
•The Company'sCompany’s ability to successfully identify, evaluate and consummate acquisitions from, and dispositions to, third parties;
•The Company's ability to close the Thermal Disposition;
•The Company'sCompany’s ability to acquire assets from GIP or CEG;
•The Company'sCompany’s ability to raiseborrow additional funds and access capital due to itsmarkets, as well as the Company’s substantial indebtedness corporate structure, market conditions or otherwise;and the possibility that the Company may incur additional indebtedness going forward;
•Changes in law, including judicial decisions;
•Hazards customary to the power production industry and power generation operations such as fuel and electricity price volatility, unusual weather conditions (including wind and solar conditions), catastrophic weather-related or other damage to facilities, unscheduled generation outages, maintenance or repairs, unanticipated changes to fuel supply costs or availability due to higher demand, shortages, transportation problems or other developments, environmental incidents, or electric transmission or gas pipeline system constraints and the possibility that the Company may not have adequate insurance to cover losses as a result of such hazards;
•The Company'sCompany’s ability to operate its businesses efficiently, manage maintenance capital expenditures and costs effectively, and generate earnings and cash flows from its asset-based businesses in relation to its debt and other obligations;
•The willingness and ability of counterparties to the Company'sCompany’s offtake agreements to fulfill their obligations under such agreements;
•The Company'sCompany’s ability to enter into contracts to sell power and procure fuel on acceptable terms and prices as current offtake agreements expire;
•Government regulation, including compliance with regulatory requirements and changes in market rules, rates, tariffs and environmental laws;
•Operating and financial restrictions placed on the Company that are contained in the project-level debt facilities and other agreements of certain subsidiaries and project-level subsidiaries generally, in the Clearway Energy Operating LLC amended and restated revolving credit facility and in the indentures governing the Senior Notes; and
•Cyber terrorism and inadequate cybersecurity, or the occurrence of a catastrophic loss and the possibility that the Company may not have adequate insurance to cover losses resulting from such hazards or the inability of the Company'sCompany’s insurers to provide coverage; and
•The Company's ability to borrow additional funds and access capital markets as well as the Company's substantial indebtedness and the possibility that the Company may incur additional indebtedness going forward.coverage.
Forward-looking statements speak only as of the date they were made, and the Company undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The foregoing review of factors that could cause the Company'sCompany’s actual results to differ materially from those contemplated in any forward-looking statements included in this Annual Report on Form 10-K should not be construed as exhaustive.
Item 1B — Unresolved Staff Comments
None.
Item 2 — Properties
Listed below are descriptions of the Company'sCompany’s interests in facilities, operations and/or projects owned or leased as of December 31, 2021.2022.
| | | Capacity | | | | Capacity | | |
| | Rated MW | | Net MW(a) | | Owner-ship | | PPA Terms | | Rated MW | | Net MW(a) | | Ownership | | PPA Terms |
| Assets | Assets | | Location | | Fuel | | COD | | Counterparty | | Expiration | Assets | | Location | | Fuel | | COD | | Counterparty | | Expiration |
| Conventional | Conventional | | | | | | | | | | | | | | | | | Conventional | | | | | | | | | | | | | | | | |
| Carlsbad | Carlsbad | | Carlsbad, CA | | 527 | | | 527 | | | 100 | % | | Natural Gas | | December 2018 | | San Diego Gas & Electric | | 2038 | Carlsbad | | Carlsbad, CA | | 527 | | | 527 | | | 100 | % | | Natural Gas | | December 2018 | | San Diego Gas & Electric | | 2038 |
| El Segundo | El Segundo | | El Segundo, CA | | 550 | | | 550 | | | 100 | % | | Natural Gas | | August 2013 | | SCE | | 2023 | El Segundo | | El Segundo, CA | | 550 | | | 550 | | | 100 | % | | Natural Gas | | August 2013 | | SCE | | 2023 - 2026 |
| GenConn Devon | GenConn Devon | | Milford, CT | | 190 | | | 95 | | | 50 | % | | Natural Gas/Oil | | June 2010 | | Connecticut Light & Power | | 2040 | GenConn Devon | | Milford, CT | | 190 | | | 95 | | | 50 | % | | Natural Gas/Oil | | June 2010 | | Connecticut Light & Power | | 2040 |
| GenConn Middletown | GenConn Middletown | | Middletown, CT | | 190 | | | 95 | | | 50 | % | | Natural Gas/Oil | | June 2011 | | Connecticut Light & Power | | 2041 | GenConn Middletown | | Middletown, CT | | 190 | | | 95 | | | 50 | % | | Natural Gas/Oil | | June 2011 | | Connecticut Light & Power | | 2041 |
| Marsh Landing | Marsh Landing | | Antioch, CA | | 720 | | | 720 | | | 100 | % | | Natural Gas | | May 2013 | | Various | | 2023 - 2030 | Marsh Landing | | Antioch, CA | | 720 | | | 720 | | | 100 | % | | Natural Gas | | May 2013 | | Various | | 2023 - 2030 |
| Walnut Creek | Walnut Creek | | City of Industry, CA | | 485 | | | 485 | | | 100 | % | | Natural Gas | | May 2013 | | SCE | | 2023 - 2026 | Walnut Creek | | City of Industry, CA | | 485 | | | 485 | | | 100 | % | | Natural Gas | | May 2013 | | SCE | | 2023 - 2026 |
| Total Conventional | Total Conventional | | 2,662 | | | 2,472 | | | Total Conventional | | 2,662 | | | 2,472 | | |
| Utility Scale Solar | Utility Scale Solar | | Utility Scale Solar | |
| Agua Caliente | Agua Caliente | | Dateland, AZ | | 290 | | | 148 | | | 51 | % | | Solar | | June 2014 | | PG&E | | 2039 | Agua Caliente | | Dateland, AZ | | 290 | | | 148 | | | 51 | % | | Solar | | June 2014 | | PG&E | | 2039 |
| Alpine | Alpine | | Lancaster, CA | | 66 | | | 66 | | | 100 | % | | Solar | | January 2013 | | PG&E | | 2033 | Alpine | | Lancaster, CA | | 66 | | | 66 | | | 100 | % | | Solar | | January 2013 | | PG&E | | 2033 |
| Avenal | Avenal | | Avenal, CA | | 45 | | | 23 | | | 50 | % | | Solar | | August 2011 | | PG&E | | 2031 | Avenal | | Avenal, CA | | 45 | | | 23 | | | 50 | % | | Solar | | August 2011 | | PG&E | | 2031 |
| Avra Valley | Avra Valley | | Pima County, AZ | | 27 | | | 27 | | | 100 | % | | Solar | | December 2012 | | Tucson Electric Power | | 2032 | Avra Valley | | Pima County, AZ | | 27 | | | 27 | | | 100 | % | | Solar | | December 2012 | | Tucson Electric Power | | 2032 |
| Blythe | Blythe | | Blythe, CA | | 21 | | | 21 | | | 100 | % | | Solar | | December 2009 | | SCE | | 2029 | Blythe | | Blythe, CA | | 21 | | | 21 | | | 100 | % | | Solar | | December 2009 | | SCE | | 2029 |
| Borrego | Borrego | | Borrego Springs, CA | | 26 | | | 26 | | | 100 | % | | Solar | | February 2013 | | San Diego Gas and Electric | | 2038 | Borrego | | Borrego Springs, CA | | 26 | | | 26 | | | 100 | % | | Solar | | February 2013 | | San Diego Gas and Electric | | 2038 |
Buckthorn Solar (b) | Buckthorn Solar (b) | | Fort Stockton, TX | | 154 | | | 154 | | | 100 | % | | Solar | | July 2018 | | City of Georgetown, TX | | 2043 | Buckthorn Solar (b) | | Fort Stockton, TX | | 150 | | | 150 | | | 100 | % | | Solar | | July 2018 | | City of Georgetown, TX | | 2043 |
| CVSR | CVSR | | San Luis Obispo, CA | | 250 | | | 250 | | | 100 | % | | Solar | | October 2013 | | PG&E | | 2038 | CVSR | | San Luis Obispo, CA | | 250 | | | 250 | | | 100 | % | | Solar | | October 2013 | | PG&E | | 2038 |
| Desert Sunlight 250 | Desert Sunlight 250 | | Desert Center, CA | | 250 | | | 63 | | | 25 | % | | Solar | | December 2014 | | SCE | | 2034 | Desert Sunlight 250 | | Desert Center, CA | | 250 | | | 63 | | | 25 | % | | Solar | | December 2014 | | SCE | | 2034 |
| Desert Sunlight 300 | Desert Sunlight 300 | | Desert Center, CA | | 300 | | | 75 | | | 25 | % | | Solar | | December 2014 | | PG&E | | 2039 | Desert Sunlight 300 | | Desert Center, CA | | 300 | | | 75 | | | 25 | % | | Solar | | December 2014 | | PG&E | | 2039 |
| Kansas South | Kansas South | | Lemoore, CA | | 20 | | | 20 | | | 100 | % | | Solar | | June 2013 | | PG&E | | 2033 | Kansas South | | Lemoore, CA | | 20 | | | 20 | | | 100 | % | | Solar | | June 2013 | | PG&E | | 2033 |
Kawailoa (b) | | Oahu, HI | | 49 | | | 24 | | | 48 | % | | Solar | | November 2019 | | Hawaiian Electric Company | | 2041 | |
Mililani I (b) (c) | | Mililani I (b) (c) | | Honolulu, HI | | 39 | | | 20 | | | 50 | % | | Solar | | July 2022 | | Hawaiian Electric Company | | 2042 |
Oahu Solar Projects (b) | Oahu Solar Projects (b) | | Oahu, HI | | 61 | | | 58 | | | 95 | % | | Solar | | September 2019 | | Hawaiian Electric Company | | 2041 | Oahu Solar Projects (b) | | Oahu, HI | | 61 | | | 61 | | | 100 | % | | Solar | | September 2019 | | Hawaiian Electric Company | | 2041 |
| Roadrunner | Roadrunner | | Santa Teresa, NM | | 20 | | | 20 | | | 100 | % | | Solar | | August 2011 | | El Paso Electric | | 2031 | Roadrunner | | Santa Teresa, NM | | 20 | | | 20 | | | 100 | % | | Solar | | August 2011 | | El Paso Electric | | 2031 |
Rosamond Central (b) | Rosamond Central (b) | | Rosamond, CA | | 192 | | | 96 | | | 50 | % | | Solar | | December 2020 | | Various | | 2035 - 2047 | Rosamond Central (b) | | Rosamond, CA | | 192 | | | 96 | | | 50 | % | | Solar | | December 2020 | | Various | | 2035 - 2047 |
| TA High Desert | TA High Desert | | Lancaster, CA | | 20 | | | 20 | | | 100 | % | | Solar | | March 2013 | | SCE | | 2033 | TA High Desert | | Lancaster, CA | | 20 | | | 20 | | | 100 | % | | Solar | | March 2013 | | SCE | | 2033 |
| Utah Solar Portfolio | Utah Solar Portfolio | | Various | | 530 | | | 530 | | | 100 | % | | Solar | | July - September 2016 | | PacifiCorp | | 2036 | Utah Solar Portfolio | | Various | | 530 | | | 530 | | | 100 | % | | Solar | | July - September 2016 | | PacifiCorp | | 2036 |
Total Utility Scale Solar | Total Utility Scale Solar | | 2,321 | | | 1,621 | | | Total Utility Scale Solar | | 2,307 | | | 1,616 | | |
| Distributed Solar | Distributed Solar | | Distributed Solar | |
DGPV Fund Projects (b) | DGPV Fund Projects (b) | | Various | | 286 | | | 286 | | | 100 | % | | Solar | | September 2015 - March 2019 | | Various | | 2030 - 2044 | DGPV Fund Projects (b) | | Various | | 286 | | | 286 | | | 100 | % | | Solar | | September 2015 - March 2019 | | Various | | 2030 - 2044 |
| Solar Power Partners (SPP) Projects | Solar Power Partners (SPP) Projects | | Various | | 25 | | | 25 | | | 100 | % | | Solar | | June 2008 - June 2012 | | Various | | 2026 - 2037 | Solar Power Partners (SPP) Projects | | Various | | 25 | | | 25 | | | 100 | % | | Solar | | June 2008 - June 2012 | | Various | | 2026 - 2037 |
| Other DG Projects | Other DG Projects | | Various | | 21 | | | 21 | | | 100 | % | | Solar | | December 2010 - October 2015 | | Various | | 2023 - 2039 | Other DG Projects | | Various | | 21 | | | 21 | | | 100 | % | | Solar | | December 2010 - October 2015 | | Various | | 2023 - 2039 |
Total Distributed Solar | Total Distributed Solar | | 332 | | | 332 | | | Total Distributed Solar | | 332 | | | 332 | | |
| Wind | Wind | | Wind | |
| Alta I | Alta I | | Tehachapi, CA | | 150 | | | 150 | | | 100 | % | | Wind | | December 2010 | | SCE | | 2035 | Alta I | | Tehachapi, CA | | 150 | | | 150 | | | 100 | % | | Wind | | December 2010 | | SCE | | 2035 |
| Alta II | Alta II | | Tehachapi, CA | | 150 | | | 150 | | | 100 | % | | Wind | | December 2010 | | SCE | | 2035 | Alta II | | Tehachapi, CA | | 150 | | | 150 | | | 100 | % | | Wind | | December 2010 | | SCE | | 2035 |
| Alta III | Alta III | | Tehachapi, CA | | 150 | | | 150 | | | 100 | % | | Wind | | February 2011 | | SCE | | 2035 | Alta III | | Tehachapi, CA | | 150 | | | 150 | | | 100 | % | | Wind | | February 2011 | | SCE | | 2035 |
| Alta IV | Alta IV | | Tehachapi, CA | | 102 | | | 102 | | | 100 | % | | Wind | | March 2011 | | SCE | | 2035 | Alta IV | | Tehachapi, CA | | 102 | | | 102 | | | 100 | % | | Wind | | March 2011 | | SCE | | 2035 |
| Alta V | Alta V | | Tehachapi, CA | | 168 | | | 168 | | | 100 | % | | Wind | | April 2011 | | SCE | | 2035 | Alta V | | Tehachapi, CA | | 168 | | | 168 | | | 100 | % | | Wind | | April 2011 | | SCE | | 2035 |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | Capacity | | | | | | | | | | |
| | | | Rated MW | | Net MW(a) | | Owner-ship | | | | | | PPA Terms |
| Assets | | Location | | | | | Fuel | | COD | | Counterparty | | Expiration |
Alta X (b) | | Tehachapi, CA | | 137 | | | 137 | | | 100 | % | | Wind | | February 2014 | | SCE | | 2038 |
Alta XI (b) | | Tehachapi, CA | | 90 | | | 90 | | | 100 | % | | Wind | | February 2014 | | SCE | | 2038 |
Black Rock (b)(d) | | Mineral and Grant Counties, WV | | 70 | | | 35 | | | 50 | % | | Wind | | December 2021 | | Toyoya and AEP | | 2036 |
| Buffalo Bear | | Buffalo, OK | | 19 | | | 19 | | | 100 | % | | Wind | | December 2008 | | Western Farmers Electric Co-operative | | 2033 |
| Crosswinds | | Ruthven, IA | | 21 | | | 21 | | | 99 | % | | Wind | | June 2007 | | Corn Belt Power Cooperative | | 2027 |
Elbow Creek (b) | | Howard County, TX | | 122 | | | 122 | | | 100 | % | | Wind | | December 2008 | | Various | | 2029 |
| Elkhorn Ridge | | Bloomfield, NE | | 81 | | | 54 | | | 66.7 | % | | Wind | | March 2009 | | Nebraska Public Power District | | 2029 |
| Forward | | Berlin, PA | | 29 | | | 29 | | | 100 | % | | Wind | | April 2008 | | Constellation NewEnergy, Inc. | | 2022 |
| Goat Wind | | Sterling City, TX | | 150 | | | 150 | | | 100 | % | | Wind | | April 2008/June 2009 | | Dow Pipeline Company | | 2025 |
| Hardin | | Jefferson, IA | | 15 | | | 15 | | | 99 | % | | Wind | | May 2007 | | Interstate Power and Light Company | | 2027 |
Langford (b) | | Christoval, TX | | 160 | | | 160 | | | 100 | % | | Wind | | December 2009/November 2020 | | Goldman Sachs | | 2033 |
| Laredo Ridge | | Petersburg, NE | | 81 | | | 81 | | | 100 | % | | Wind | | February 2011 | | Nebraska Public Power District | | 2031 |
Lookout (b) | | Berlin, PA | | 38 | | | 38 | | | 100 | % | | Wind | | October 2008 | | Southern Maryland Electric Cooperative | | 2030 |
Mesquite Sky (b) | | Callahan County, TX | | 340 | | | 170 | | | 50 | % | | Wind | | December 2021 | | Various | | 2033 - 2036 |
Mesquite Star (b) | | Fisher County, TX | | 419 | | | 210 | | | 50 | % | | Wind | | June 2020 | | Various | | 2032 - 2035 |
| Mt Storm | | Mt Storm, WV | | 264 | | | 264 | | | 100 | % | | Wind | | October 2008 | | Citigroup | | 2031 |
| Ocotillo | | Forsan, TX | | 59 | | | 59 | | | 100 | % | | Wind | | November 2008 | | N/A | | |
| Odin | | Mountain Lake, MN | | 21 | | | 21 | | | 100 | % | | Wind | | June 2008 | | Missouri River Energy Services | | 2028 |
Pinnacle (b) | | Keyser, WV | | 54 | | | 54 | | | 100 | % | | Wind | | December 2011/December 2021 | | Maryland Department of General Services and University System of Maryland | | 2031 |
Rattlesnake (b) (c) | | Ritzville, WA | | 160 | | | 160 | | | 100 | % | | Wind | | December 2020 | | Avista Corporation | | 2040 |
| San Juan Mesa | | Elida, NM | | 120 | | | 90 | | | 75 | % | | Wind | | December 2005 | | Southwestern Public Service Company | | 2025 |
| Sleeping Bear | | Woodward, OK | | 95 | | | 95 | | | 100 | % | | Wind | | October 2007 | | Public Service Company of Oklahoma | | 2032 |
| South Trent | | Sweetwater, TX | | 101 | | | 101 | | | 100 | % | | Wind | | January 2009 | | AEP Energy Partners | | 2029 |
| Spanish Fork | | Spanish Fork, UT | | 19 | | | 19 | | | 100 | % | | Wind | | July 2008 | | PacifiCorp | | 2028 |
Spring Canyon II (b) | | Logan County, CO | | 34 | | | 31 | | | 90.1 | % | | Wind | | October 2014 | | Platte River Power Authority | | 2039 |
Spring Canyon III (b) | | Logan County, CO | | 29 | | | 26 | | | 90.1 | % | | Wind | | December 2014 | | Platte River Power Authority | | 2039 |
| Taloga | | Putnam, OK | | 130 | | | 130 | | | 100 | % | | Wind | | July 2011 | | Oklahoma Gas & Electric | | 2031 |
Wildorado (b) | | Vega, TX | | 161 | | | 161 | | | 100 | % | | Wind | | April 2007 | | Southwestern Public Service Company | | 2027 |
| Total Wind | | 3,739 | | | 3,262 | | | | | | | | | | | |
| Thermal Generation | | | | | | | | | | | | | | |
| CA Fuel Cell | | Tulare, CA | | 3 | | | 3 | | | 100 | % | | Natural Gas | | May 2018 | | City of Tulare | | 2038 |
| | | | | | | | | | | | | | | | |
| ECP Uptown Campus | | Pittsburgh, PA | | 6 | | | 6 | | | 100 | % | | Natural Gas | | May 2019 | | Duquesne University | | 2059 |
| Energy Center - Pittsburgh | | Pittsburgh, PA | | 7 | | | 7 | | | 100 | % | | Diesel | | January 2019 | | University of Pittsburgh Medical Center | | 2038 |
| Energy Center Caguas | | Caguas, PR | | 3 | | | 3 | | | 100 | % | | Natural Gas | | September 2020 | | Viatris Pharmaceuticals | | 2032 |
| Paxton Creek Cogen | | Harrisburg, PA | | 12 | | | 12 | | | 100 | % | | Natural Gas | | November 1986 | | Power sold into PJM markets |
| Princeton Hospital | | Princeton, NJ | | 5 | | | 5 | | | 100 | % | | Natural Gas | | January 2012 | | Princeton Hospital | | 2025 |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | Capacity | | | | | | | | | | |
| | | | Rated MW | | Net MW(a) | | Owner-ship | | | | | | PPA Terms |
| Assets | | Location | | | | | Fuel | | COD | | Counterparty | | Expiration |
| Tucson Convention Center | | Tucson, AZ | | 2 | | | 2 | | | 100 | % | | Natural Gas | | January 2003 | | City of Tucson | | 2023 |
| University of Bridgeport | | Bridgeport, CT | | 1 | | | 1 | | | 100 | % | | Natural Gas | | April 2015 | | University of Bridgeport | | 2034 |
Total Thermal Generation (e) | | 39 | | | 39 | | | | | | | | | | | |
| Total Clearway Energy LLC | | 9,093 | | | 7,726 | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | Capacity | | | | | | | | | | |
| | | | Rated MW | | Net MW(a) | | Ownership | | | | | | PPA Terms |
| Assets | | Location | | | | | Fuel | | COD | | Counterparty | | Expiration |
Alta X (b) | | Tehachapi, CA | | 137 | | | 137 | | | 100 | % | | Wind | | February 2014 | | SCE | | 2038 |
Alta XI (b) | | Tehachapi, CA | | 90 | | | 90 | | | 100 | % | | Wind | | February 2014 | | SCE | | 2038 |
Black Rock (b) | | Mineral and Grant Counties, WV | | 115 | | | 58 | | | 50 | % | | Wind | | December 2021 | | Toyota and AEP | | 2036 |
| Buffalo Bear | | Buffalo, OK | | 19 | | | 19 | | | 100 | % | | Wind | | December 2008 | | Western Farmers Electric Co-operative | | 2033 |
| Capistrano Wind Portfolio | | Various | | 413 | | | 413 | | | 100 | % | | Wind | | 2008-2012 | | Various | | 2030 - 2033 |
Elbow Creek (b) | | Howard County, TX | | 122 | | | 122 | | | 100 | % | | Wind | | December 2008 | | Various | | 2029 |
| Elkhorn Ridge | | Bloomfield, NE | | 81 | | | 54 | | | 66.7 | % | | Wind | | March 2009 | | Nebraska Public Power District | | 2029 |
| Forward | | Berlin, PA | | 29 | | | 29 | | | 100 | % | | Wind | | April 2008 | | Constellation NewEnergy, Inc. | | 2025 |
| Goat Wind | | Sterling City, TX | | 150 | | | 150 | | | 100 | % | | Wind | | April 2008/June 2009 | | Dow Pipeline Company | | 2025 |
| | | | | | | | | | | | | | | | |
Langford (b) | | Christoval, TX | | 160 | | | 160 | | | 100 | % | | Wind | | December 2009/November 2020 | | Goldman Sachs | | 2033 |
| Laredo Ridge | | Petersburg, NE | | 81 | | | 81 | | | 100 | % | | Wind | | February 2011 | | Nebraska Public Power District | | 2031 |
| Lookout | | Berlin, PA | | 38 | | | 38 | | | 100 | % | | Wind | | October 2008 | | Southern Maryland Electric Cooperative | | 2030 |
Mesquite Sky (b) | | Callahan County, TX | | 340 | | | 170 | | | 50 | % | | Wind | | December 2021 | | Various | | 2033 - 2036 |
Mesquite Star (b) | | Fisher County, TX | | 419 | | | 210 | | | 50 | % | | Wind | | May 2020 | | Various | | 2032 - 2035 |
| Mt. Storm | | Grant County, WV | | 264 | | | 264 | | | 100 | % | | Wind | | October 2008 | | Citigroup | | 2031 |
| Ocotillo | | Forsan, TX | | 55 | | | 55 | | | 100 | % | | Wind | | November 2008 | | N/A | | |
| Odin | | Mountain Lake, MN | | 21 | | | 21 | | | 100 | % | | Wind | | June 2008 | | Missouri River Energy Services | | 2028 |
Pinnacle (b) | | Keyser, WV | | 54 | | | 54 | | | 100 | % | | Wind | | December 2011/December 2021 | | Maryland Department of General Services and University System of Maryland | | 2031 |
Rattlesnake (b) (e) | | Ritzville, WA | | 160 | | | 160 | | | 100 | % | | Wind | | December 2020 | | Avista Corporation | | 2040 |
| San Juan Mesa | | Elida, NM | | 120 | | | 90 | | | 75 | % | | Wind | | December 2005 | | Southwestern Public Service Company | | 2025 |
| Sleeping Bear | | Woodward, OK | | 95 | | | 95 | | | 100 | % | | Wind | | October 2007 | | Public Service Company of Oklahoma | | 2032 |
| South Trent | | Sweetwater, TX | | 101 | | | 101 | | | 100 | % | | Wind | | January 2009 | | AEP Energy Partners | | 2029 |
| Spanish Fork | | Spanish Fork, UT | | 19 | | | 19 | | | 100 | % | | Wind | | July 2008 | | PacifiCorp | | 2028 |
Spring Canyon II (b) | | Logan County, CO | | 34 | | | 31 | | | 90.1 | % | | Wind | | October 2014 | | Platte River Power Authority | | 2039 |
Spring Canyon III (b) | | Logan County, CO | | 29 | | | 26 | | | 90.1 | % | | Wind | | December 2014 | | Platte River Power Authority | | 2039 |
| Taloga | | Putnam, OK | | 130 | | | 130 | | | 100 | % | | Wind | | July 2011 | | Oklahoma Gas & Electric | | 2031 |
Wildorado (b) | | Vega, TX | | 161 | | | 161 | | | 100 | % | | Wind | | April 2007 | | Southwestern Public Service Company | | 2027 |
Total Wind (d) | | 4,157 | | | 3,658 | | | | | | | | | | | |
| | | | | | | | | | | | | | | | |
| Total Clearway Energy LLC | | 9,458 | | | 8,078 | | | | | | | | | | | |
(a) Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company'sCompany’s percentage ownership in the facility as of December 31, 2021.2022.
(b) Projects are part of tax equity arrangements, as further described in Item 15 — Note 2, Summary of Significant Accounting Policies.
(c) Includes storage capacity that matches the facility’s rated generating capacity.
(d) Typical average capacity factors are 25% for solar facilities and 25-45% for wind facilities. For the year ended December 31, 2022, the Company's solar and wind facilities had weighted-average capacity factors of 28% and 30%, respectively.
(e)Rattlesnake has a deliverable capacity of 144 MW.
(d) Black Rock's rated capacity is 115 MW, of which 70 MW, representing fourteen of the twenty-three wind turbines, became operational as of December 31, 2021. The remaining 45 MW of rated capacity became operational in January 2022.
(e) Includes thermal assets held for sale as of December 31, 2021, as further described in Item 15 — Note 3, Acquisitions and Dispositions.
The following table summarizes the Company's thermal steam and chilled water facilities as of December 31, 2021:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Name and Location of Facility | | Thermal Energy Customers (steam/chilled water) | | % Owned | | Rated Megawatt
Thermal
Equivalent
Capacity (MWt) | | Net Megawatt Thermal Equivalent Capacity (MWt) (a) | | Generating
Capacity |
| Energy Center Minneapolis, MN | | 100 steam | | 100 | % | | 284 | | 284 | | Steam: 1,075 MMBtu/hr. |
| | 55 chilled water | | 100 | % | | 136 | | 136 | | | Chilled water: 38,700 tons |
| ECP Uptown Campus, PA | | Duquesne University | | 100 | % | | 53 | | 53 | | | Steam: 181 MMBtu/hr. |
| | Duquesne University | | 100 | % | | 24 | | | 24 | | | Chilled water: 5,790 tons |
| Energy Center San Francisco, CA | | 180 steam | | 100 | % | | 133 | | | 133 | | | Steam: 454 MMBtu/hr. |
| Energy Center Omaha, NE | | 60 steam | | 100 | % | | 180 | | 180 | | Steam: 675 MMBtu/hr. |
| | 65 chilled water | | 100 | % | | 88 | | 88 | | Chilled water: 28,000 tons |
| Energy Center Harrisburg, PA | | 115 steam | | 100 | % | | 94 | | 94 | | Steam: 370 MMBtu/hr. |
| | 5 chilled water | | 100 | % | | 14 | | | 14 | | | Chilled water: 3,900 tons |
| Energy Center Phoenix, AZ | | 40 chilled water | | 73 % (b) | | 144 | | 104 | | Chilled water 41,020 tons |
| | | | 24 | % | | 5 | | | 1 | | | Steam: 17 MMBtu/hr. |
| Energy Center Pittsburgh, PA | | 25 steam | | 100 | % | | 118 | | 118 | | Steam: 452 MMBtu/hr. |
| | 30 chilled water | | 100 | % | | 68 | | | 68 | | | Chilled water: 22,224 tons |
| Energy Center San Diego, CA | | 20 chilled water | | 100 | % | | 31 | | | 31 | | | Chilled water: 9,295 tons |
| Energy Center Princeton, NJ | | Princeton HealthCare System | | 100 | % | | 21 | | | 21 | | | Steam: 72 MMBtu/hr. |
| | Princeton HealthCare System | | 100 | % | | 17 | | | 17 | | | Chilled water: 4,700 tons |
| Energy Center Caguas, PR | | Viatris Pharmaceuticals | | 100 | % | | 1 | | | 1 | | | Steam: 4 MMBtu/hr. |
| | Viatris Pharmaceuticals | | 100 | % | | 3 | | | 3 | | | Chilled water: 800 tons |
Total generating capacity (c) | | | | | | 1,414 | | | 1,370 | | | |
(a) Net megawatt thermal equivalent capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of December 31, 2021.
(b) Net MWt capacity excludes 44 MWt available under the right-to-use provisions contained in agreements between one of the Company's thermal facilities and certain of its customers.
(c) Includes thermal assets held for sale as of December 31, 2021, as further described in Item 15 — Note 3, Acquisitions and Dispositions.
Item 3 — Legal Proceedings
See Item 15 — Note 14, Commitments and Contingencies, to the Consolidated Financial Statements for discussion of the material legal proceedings to which the Company is a party or of which any of its properties is subject.
Item 4 — Mine Safety Disclosures
Not applicable.
PART II
Item 5 — Market for Registrant'sRegistrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Market Information and Holders
As of the date of this report, there is no publicly-traded market for the Company'sCompany’s membership units. All of the Company'sCompany’s Class A and Class C units are held by Clearway, Inc. and all of the Company'sCompany’s Class B and Class D units are held by CEG.
Distributions
The following table lists the distributions paid on the Company'sCompany’s Class A, Class B, Class C and Class D units during the year ended December 31, 2021:2022:
| | | Fourth Quarter 2021 | | Third Quarter 2021 | | Second Quarter 2021 | | First Quarter 2021 | | Fourth Quarter 2022 | | Third Quarter 2022 | | Second Quarter 2022 | | First Quarter 2022 |
| Distributions per Class A and Class B unit | Distributions per Class A and Class B unit | $ | 0.3400 | | | $ | 0.3345 | | | $ | 0.3290 | | | $ | 0.3240 | | Distributions per Class A and Class B unit | $ | 0.3672 | | | $ | 0.3604 | | | $ | 0.3536 | | | $ | 0.3468 | |
| Distributions per Class C and Class D unit | Distributions per Class C and Class D unit | $ | 0.3400 | | | $ | 0.3345 | | | $ | 0.3290 | | | $ | 0.3240 | | Distributions per Class C and Class D unit | 0.3672 | | | 0.3604 | | | 0.3536 | | | 0.3468 | |
On February 17, 2022,15, 2023, the Company declared a quarterly distribution on its Class A, Class B, Class C and Class D units of $0.3468$0.3745 per unit payable on March 15, 2022.2023.
Item 6 — Reserved
Item 7 — Management'sManagement’s Discussion and Analysis of Financial Condition and the Results of Operations
As you read this discussion and analysis, refer to the Company'sCompany’s Consolidated Statements of OperationsIncome to this Form 10-K. Also refer to Item 1 — Business and Item 1A — Risk Factors, which include detailed discussions of various items impacting the Company'sCompany’s business, results of operations and financial condition. Discussions of the year ended December 31, 20192020 that are not included in this Annual Report on Form 10-K and year-to-year comparisons of the year ended December 31, 20202021 and the year ended December 31, 20192020 can be found in “Management’s Discussion and Analysis of Financial Condition and the Results of Operations” in Part II, Item 7 of the Company’s Annual Report on Form 10-K for the year ended December 31, 2020.2021.
The discussion and analysis below has been organized as follows:
•Executive Summary, including a description of the business and significant events that are important to understanding the results of operations and financial condition;
•Results of operations, including an explanation of significant differences between the periods in the specific line items of the consolidated statements of operations;income;
•Financial condition addressing liquidity position, sources and uses of cash, capital resources and requirements, commitments and off-balance sheet arrangements;
•Known trends that may affect the Company’s results of operations and financial condition in the future; and
•Critical accounting policies which are most important to both the portrayal of the Company'sCompany’s financial condition and results of operations, and which require management'smanagement’s most difficult, subjective or complex judgment.
Executive Summary
Introduction and Overview
Clearway Energy LLC, together with its consolidated subsidiaries, or the Company, is an energy infrastructure investor with a focus on investments in clean energy and owner of modern, sustainable and long-term contracted assets across North America. The Company is sponsored by GIP and TotalEnergies through GIP'sthe portfolio company, Clearway Energy Group LLC, or CEG, which became equally owned by GIP and TotalEnergies as of September 12, 2022, when TotalEnergies acquired, through its investment in an intermediate holding company, 50% of GIP’s interest in CEG. 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.
The Company is one of the largest renewable energy owners in the U.S. with over 5,0005,500 net MW of installed wind and solar generation projects. The Company'sCompany’s over 9,0008,000 net MW of assets also includes approximately 2,500 net MW of environmentally-sound, highly efficient natural gas-fired generation facilities as well as the Thermal Business.facilities. Through this environmentally-sound, diversified and primarily contracted portfolio, the Company endeavors to increase distributions to its unit holders. The majoritySubstantially all of the Company's generation assetsCompany’s revenues are underderived from long-term contractual arrangements for the output or capacity from these assets. The weighted average remaining contract duration of these offtake agreements was approximately 1211 years as of December 31, 20212022 based on CAFD.
Significant Events
Thermal Disposition
•On October 22, 2021, Clearway Energy Operating LLC entered into a binding agreement to sellMay 1, 2022, the Company completed the sale of 100% of its interests in the Thermal Business to KKR for total consideration of $1.9 billion, subject to customary closing adjustments, which is referred to herein as the Thermal Disposition. Based on current estimates, the Company expects total net cash proceeds of approximately $1.35$1.46 billion, after the assumptioninclusive of project level debt, estimated taxes and obligations owed,working capital adjustments, which excludes approximately $18 million in transaction expenses and capital expenditures required to be funded pursuant tothat were incurred in connection with the terms and conditionsdisposition. The transaction resulted in a gain on sale of business of approximately $1.29 billion, which is net of the definitive agreement. The closing of the$18 million in transaction is subject to various customary closing conditions, approvalsexpenses referenced above. See Item 15 — Note 3, Acquisitions and consents and is expected to close in the first half of 2022. The Company's Thermal segment is comprised solely of the Thermal Business's results of operations.Dispositions, for further discussion.
Corporate Level FinancingCapistrano Wind Portfolio Acquisition
•On November 30, 2021, Clearway Energy Operating LLC entered into a senior secured bridge credit agreement, or the Bridge Loan Agreement, that provides for a term loan facility in an aggregate principal amount of $335 million. The Bridge Loan Agreement will mature no later than November 29, 2022. The Company intends to use proceeds from the Thermal Disposition to repay the outstanding principal balance of the term loans under the Bridge Loan Agreement. The borrowings under the term loan facility were used to acquire the Utah Solar Portfolio on December 1, 2021, as described below.
•On November 30, 2021, Clearway Energy Operating LLC entered into the Sixth Amendment to Amended and Restated Credit Agreement to provide for an increase of the maximum permitted Borrower Leverage Ratio to 6.00 to 1.00 during the period commencing on November 30, 2021 and ending on the leverage period termination date, which is the earliest of (i) two business days following the consummation of the Thermal Disposition, (ii) 120 days following the termination or expiration of the binding agreement entered into with KKR to sell the Thermal Business and (iii) the maturity date of the Bridge Loan Agreement. The Sixth Amendment also permits the incurrence of the term loan facility under the Bridge Loan Agreement, permits the incurrence of hedging obligations, permits the prepayment of indebtedness and implements certain other technical modifications.
•On October 1, 2021, Clearway Energy Operating LLC completed the sale of $350 million of senior unsecured notes due 2032, or the 2032 Senior Notes. The 2032 Senior Notes bear interest at 3.750% and mature on January 15, 2032. The net proceeds from the 2032 Senior Notes were used, together with existing corporate liquidity, to repurchase the 2026 Senior Notes, as described below.
•In October 2021, the Company repurchased and redeemed an aggregate principal amount of $350 million of the 2026 Senior Notes, through the cash tender offer announced on September 24, 2021 and the redemption of the remaining amount on October 25, 2021. The repurchases and redemption were effectuated at a premium of approximately 103% for total consideration of $359 million.
•On March 9, 2021, Clearway Energy Operating LLC completed the sale of $925 million of senior unsecured notes due 2031, or the 2031 Senior Notes. The 2031 Senior Notes bear interest at 3.750% and mature on February 15, 2031. The net proceeds from the 2031 Senior Notes were used to repurchase the 2025 Senior Notes, as described below, as well as to repay amounts outstanding under the Company’s revolving credit facility and for general corporate purposes.
•In March 2021, the Company repurchased and redeemed an aggregate principal amount of $600 million of the 2025 Senior Notes, through the cash tender offer announced on March 2, 2021 and the redemption of the remaining amount on March 17, 2021. The repurchases and redemption were effectuated at a premium of approximately 106% for total consideration of $636 million.
Project-Level Financing Activities
•On March 10, 2021, the Company entered into a financing agreement for non-recourse debt for a total commitment of $126 million related to the repowering of the Pinnacle wind project. The debt consists of a construction loan at an interest rate of LIBOR plus 1.00%. The Company's initial borrowings of $79 million were utilized to repay $53 million of the outstanding balance under the Tapestry financing agreement, which related to the Pinnacle wind project, and to reimburse Clearway Renew LLC for previous contributions and pay vendor invoices and fees. On December 15, 2021, the Company repaid the outstanding principal amount of $117 million utilizing existing corporate liquidity, along with proceeds from tax equity.
Third- Party Acquisitions
•On December 1, 2021,August 22, 2022, the Company acquired the remaining 50% equity interestCapistrano Wind Portfolio, which consists of five wind projects located in the Utah Solar PortfolioNebraska, Texas and Wyoming with a combined capacity of 413 MW, from Dominion Solar Projects III, Inc.,Capistrano Wind Partners LLC, an indirect subsidiary of CEG, for approximately $335 million before working capital and purchase price adjustments in the net amount of $5 million, representing total net consideration of $330approximately $239 million. Borrowings under the Bridge Loan Agreement were used to fund the acquisition. The Utah Solar Portfolio consists of seven utility-scale solar farms located in Utah representing 530 MW of capacity. The assets within the portfolio sell power subject to 20-year PPAs with PacifiCorp that have approximatelySee Item 15 years remaining under the agreements. Following the close of the transaction, the Company owns 100% of the membership interests in the Utah Solar Portfolio. The Company removed its equity method investment— Note 3, Acquisitions and consolidates its interests in the Utah Solar Portfolio within the Renewables segment from the date of the acquisition.Dispositions, for further discussion.
•On April 23, 2021, the Company acquired 100% of the equity interests in NedPower Mount Storm LLC, or Mt. Storm, from Castleton Commodities International for approximately $96 million before working capital and purchase price adjustments in the net amount of $4 million, representing a total net consideration of $100 million. Mt. Storm is a 264 MW wind project located in Grant County, West Virginia. Mt. Storm has a 10-year energy hedge with an investment-grade counterparty.
•On February 3, 2021, the Company acquired an additional 35% equity interest in the Agua Caliente solar project from NRG Energy, Inc. for $202 million. Agua Caliente is a 290 MW solar project located in Dateland, Arizona in which the Company previously owned a 16% equity interest. The project has a 25-year PPA with PG&E, with approximately 17 years remaining under the agreement. Following the close of the transaction, the Company owns a 51% equity interest in Agua Caliente. The Company removed its equity method investment and consolidates its interest in Agua Caliente within the Renewables segment from the date of the acquisition.
Drop Down Transactions
•On December 29, 2021,February 17, 2023, the Company, through its indirect subsidiary Lighthouse Renewable Holding Sub LLC,a partnership with a third-party investor, acquired the Class B membership interestsan interest in Black Rock Wind HoldingDaggett TargetCo LLC from Clearway Renew LLC, a subsidiary of CEG, for $60 million in cash consideration $37of $21 million. The third-party investor also contributed cash consideration of $129 million, of which was paid on December 29, 2021, withutilized to acquire their portion of the remaining $23 million paid in February 2022 after all remaining turbines were operational. Lighthouse Renewable Holding Subacquired entity. Daggett TargetCo LLC is a wholly-owned subsidiary of Lighthouse Renewable Holdco LLC, which is a partnership between the Company and a third-party investor. The Class A membership interests of Black Rock Wind Holding LLC are owned by another third-party investor. Black Rock Wind Holding LLC, through its subsidiary, is the primary beneficiary and consolidates its interests in a tax equity fund, Black RockDaggett TE Holdco LLC, that holds the Black Rock windowner of the Daggett 3 solar project, a 115300 MW utility scale windsolar project with matching storage capacity that is currently under construction and located in Mineral CountySan Bernardino, California. See Item 15 — Note 3, Acquisitions and Grant County, West Virginia. As of December 31, 2021, 70 MW of the 115 MW rated capacity were operational, representing fourteen of the twenty-three wind turbines, and the remaining 45 MW rated capacity became operational in January 2022. A majority of the project’s output is backed by contracts with investment-grade counterparties with a 15-year weighted average contract life.
Dispositions, for further discussion.
•On December 17, 2021, the Company through its indirect subsidiary Lighthouse Renewable Holdco 2 LLC, acquired the Class B membership interests in Mesquite Sky Holding LLC from Clearway Renew LLC, a subsidiary of CEG, for $61 million in cash consideration. Lighthouse Renewable Holdco 2 LLC is a partnership between the Company and a third-party investor. The Class A membership interests of Mesquite Sky Holding LLC are owned by another third-party investor. Mesquite Sky Holding LLC, through its subsidiary, is the primary beneficiary and consolidates its interests in a tax equity fund, Mesquite Sky TE Holdco LLC that holds the Mesquite Sky wind project, a 340 MW utility scale wind project located in Callahan County, Texas, which achieved commercial operations in December 2021. A majority of the project’s output is backed by contracts with investment-grade counterparties with a 12-year weighted average contract life.
•On October 28, 2021,23, 2022, the Company, through an indirect subsidiary, entered into an agreement with CEG to acquire the Class A membership interests in the Daggett 3 solar project upon the project meeting certain milestones. Daggett 3 is a 300 MW solar generating facility under development with a combined 144 MW and 576 MWh battery energy storage system located in San Bernardino, California. The Company expectspartnership formed to invest approximately $21 million, subject to closing adjustments. Commercial operations ofhold the facility and the Company's investment are expected to occur in 2022.
•On August 2, 2021, the CEG ROFO Agreement was amended to remove the 100 MW Wildflower utility scale solar project from the ROFO pipeline.
•On June 24, 2021, the Company, through an indirect subsidiary, entered into agreements with CEG to acquire the Class A membership interests in the Mililani IVictory Pass and WaiawaArica solar and energy storage projects, which are both located in Riverside, California, upon the projects reaching certain milestones.milestones for a total purchase price of approximately $228 million in cash, subject to customary working capital adjustments. Victory Pass is a 200 MW solar facility and Arica is a 263 MW solar facility, each with an energy storage system. Upon the closing of the transaction, which is expected in the second half of 2023, the Company will own 40% of the partnership holding interests in Victory Pass and Arica, which are anticipated to be held in a tax equity fund with another third-party investor.
•On October 3, 2022, the Company, through a partnership with a third-party investor, acquired Waiawa BL Borrower Holdco LLC, the indirect owner, through its ownership interests in and consolidation of a tax equity fund, of the Waiawa solar project, a 36 MW solar project with matching storage capacity located in Honolulu, Hawaii, from Clearway Renew LLC for cash consideration of $20 million. The third-party investor also contributed cash consideration of $12 million, which was utilized to acquire their portion of the acquired entity. See Item 15 — Note 3, Acquisitions and Dispositions, for further discussion.
•On March 25, 2022, the Company, through a partnership with a third-party investor, acquired Mililani BL Borrower Holdco LLC, the indirect owner, through its ownership interests in and consolidation of a tax equity fund, of the Mililani I issolar project, a 39 MW solar generating facility under developmentproject with a combined 39 MW and 156 MWh battery energymatching storage systemcapacity located in Honolulu, Hawaii. Waiawa is a 36 MW solar generating facility under development with a combined 36 MW and 144 MWh battery energy storage system located in Honolulu, Hawaii.Hawaii, from Clearway Renew LLC for cash consideration of $22 million. The Company expectsthird-party investor also contributed cash consideration of $14 million, which was utilized to invest approximately $39 million, subject to closing adjustments. Commercial operationsacquire their portion of the facilitiesacquired entity. See Item 15 — Note 3, Acquisitions and the Company's investment are expected to occur in 2022.Dispositions, for further discussion.
•OnIn February 26,2022, in connection with 2021 Black Rock Drop Down, the Company throughpaid an indirect subsidiary, entered into an amended partnership agreementadditional $23 million to Clearway Renew LLC as final funding after all remaining turbines of the project became operational. Concurrent with CEGthe final funding, the $59 million that was contributed in 2021 by third-party investors was released to repower the Pinnacle wind project, a 54 MW wind facility located in Mineral County, West Virginia. The existing Pinnacle wind power purchase agreements will continue to run through 2031. On March 10, 2021, the Pinnacle wind project acquired equipment from CEGClearway Renew LLC. See Item 15 — Note 3, Acquisitions and Dispositions, for $21 million in cash consideration. On December 14, 2021, the repowering project reached COD and on December 15, 2021, the Company funded $64 million in corporate capital, which was utilized in part to repay the Pinnacle Repowering Partnership Holdco LLC construction loan, along with proceeds from tax equity.
•On January 12, 2021, the Company acquired 100% of CEG's equity interest and a third-party investor's minority interest in CWSP Rattlesnake Holding LLC for $132 million in cash consideration. CWSP Rattlesnake Holding LLC indirectly consolidates the Rattlesnake wind project, a 160 MW wind facility with 144 MW deliverable capacity located in Adams County, Washington that achieved commercial operations in December 2020. The Company's net capital commitment was $119 million after proceeds from a state sales and use tax refund, which was received in May 2021. The project has a 20-year PPA, which began when the facility reached commercial operations.further discussion.
Resource Adequacy Agreements
•On September 28, 2021, Walnut CreekIn August 2022, the Company contracted with SCE to sell 483 MW100% of Resource Adequacy, which is the full net qualifyingEl Segundo’s available capacity of the plant, commencing in JuneAugust 2023 and ending in DecemberAugust 2026.
•On September 10, 2021, Marsh LandingIn July 2022, the Company contracted with PG&Eseveral load serving entities to sell approximately 500 MWthe remaining 20% of Resource AdequacyMarsh Landing’s available capacity commencing in May 2023. The contract isagreements are for approximately three years. On May 3, 2021, Marsh Landing contracted with a California Load Serving Entity to sell 100 MW of Resource Adequacy commencing in May 2023. The contract is for approximately seven and a half years. Collectively, these contracts representMarsh Landing’s capacity is now 100% contracted for a weighted average contract tenor of approximately 80% offour years commencing in May 2023.
Corporate Financing Activities
•On May 3, 2022, the plant's net qualifying capacity.Company repaid (i) $305 million in outstanding borrowings under the revolving credit facility and (ii) $335 million in outstanding borrowings under the Bridge Loan Agreement utilizing proceeds received from the Thermal Disposition. See Item 15 — Note 10, Long-term Debt, for further discussion.
February 2021 Winter Events in TexasProject-level Financing Activities
•In February 2021, Texas experienced extreme winter weather conditions in which certainconnection with the Capistrano Wind Portfolio acquisition and the 2022 Drop Downs of Waiawa and Mililani I, the Company assumed non-recourse project-level debt. See Item 15 — Note 10, Long-term Debt, for further discussion of the Company'snon-recourse project-level debt associated with each project.
•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.
•On March 16, 2022, the Company 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 projectsprojects. The proceeds from the term loan were unableused to operate and experienced outages due topay off the weather conditions at that time. Due to this event, and inclusiveexisting debt in the amount of amounts$186 million related to third-party equity investors, the Company recorded a reduction of approximately $50 million in revenue in the first quarter of 2021Laredo Ridge, Tapestry Wind LLC and Viento Funding II, LLC and to settle obligationspay related financing costs. See Item 15 — Note 10, Long-term Debt, for wind facilities during the extreme weather conditions. After factoring in third-party equity investor contributions, the cash impact to the Company during the first quarter of 2021 was approximately $25 million.further discussion.
Environmental Matters and Regulatory Matters
Details of environmental matters and regulatory matters are presented in Item 1 — Business, Regulatory Matters and Item 1A — Risk Factors. Details of some of this information relate to costs that may impact the Company'sCompany’s financial results.
Trends or Matters Affecting Results of Operations and Future Business Performance
Wind and Solar Resource Availability
The availability of the wind and solar resources affects the financial performance of the wind and solar facilities, which may impact the Company’s overall financial performance. Due to the variable nature of the wind and solar resources, the Company cannot predict the availability of the wind and solar resources and the potential variances from expected performance levels from quarter to quarter. To the extent the wind and solar resources are not available at expected levels, it could have a negative impact on the Company’s financial performance for such periods.
Recent Developments Affecting Industry Conditions and the Company's Business
COVID-19
In response to the ongoing coronavirus (COVID-19) pandemic, the Company has implemented preventative measures and developed corporate and regional response plans to protect the health and safety of its employees, customers and other business counterparties, while supporting the Company's suppliers and customers' operations to the best of its ability in the circumstances. The Company continues to promote heightened awareness and vigilance, hygiene, and implementation of more stringent cleaning protocols across its facilities and operations and continues to evaluate these measures, response plans and business practices in light of the evolving effects of COVID-19 and its variants.
As of the date of this report, the Company has not experienced any material financial or operational impacts related to COVID-19, or variants thereof. All of the Company’s facilities have remained operational. The Company has experienced a decrease in volumetric sales on a weather normalized basis at certain Thermal locations in part due to COVID-19 related impacts, which has not resulted in any material financial impacts to the Company. The Company believes that all of its accounts receivable balances as of December 31, 2021 are collectible. The Company will continue to assess collectability based on any future developments.
The Company cannot predict the full impact that COVID-19 and its variants will have on the Company’s financial expectations, its financial condition, results of operations and cash flows, its ability to make distributions to its unit holders and its ability to satisfy its debt service obligations at this time, due to numerous uncertainties. The ultimate impact will depend on future developments, including, among others, the ultimate geographic spread of the virus and related variants, the consequences of governmental and other measures designed to prevent the spread of the virus, the development of effective treatments, including vaccines, the duration of the pandemic, actions taken by governmental authorities, customers, suppliers and other third parties, workforce availability and the timing and extent to which normal economic and operating conditions resume For additional discussion regarding risks associated with the COVID-19 pandemic, see Part I, Item 1A, Risk Factors.
Consolidated Results of Operations
The following table provides selected financial information: | | | Year ended December 31, | | Year ended December 31, |
| (In millions) | (In millions) | 2021 | | 2020 | | 2019 | (In millions) | 2022 | | 2021 | | 2020 |
| Operating Revenues | Operating Revenues | | | | | | Operating Revenues | | | | | |
| Energy and capacity revenues | Energy and capacity revenues | $ | 1,425 | | | $ | 1,234 | | | $ | 1,072 | | Energy and capacity revenues | $ | 1,465 | | | $ | 1,425 | | | $ | 1,234 | |
| Other revenues | Other revenues | 92 | | | 53 | | | 40 | | Other revenues | 82 | | | 92 | | | 53 | |
| Contract amortization | Contract amortization | (144) | | | (88) | | | (71) | | Contract amortization | (175) | | | (144) | | | (88) | |
| Mark-to-market for economic hedges | Mark-to-market for economic hedges | (87) | | | — | | | (9) | | Mark-to-market for economic hedges | (182) | | | (87) | | | — | |
| Total operating revenues | Total operating revenues | 1,286 | | | 1,199 | | | 1,032 | | Total operating revenues | 1,190 | | | 1,286 | | | 1,199 | |
| Operating Costs and Expenses | Operating Costs and Expenses | | | | | | Operating Costs and Expenses | | | | | |
| Cost of fuels | Cost of fuels | 75 | | | 73 | | | 74 | | Cost of fuels | 29 | | | 75 | | | 73 | |
| | Operations and maintenance | Operations and maintenance | 279 | | | 219 | | | 191 | | Operations and maintenance | 295 | | | 279 | | | 219 | |
| Other costs of operations | Other costs of operations | 97 | | | 74 | | | 72 | | Other costs of operations | 111 | | | 97 | | | 74 | |
| Depreciation, amortization and accretion | Depreciation, amortization and accretion | 509 | | | 428 | | | 401 | | Depreciation, amortization and accretion | 512 | | | 509 | | | 428 | |
| Impairment losses | Impairment losses | 6 | | | 24 | | | 33 | | Impairment losses | 16 | | | 6 | | | 24 | |
| General and administrative | General and administrative | 38 | | | 33 | | | 27 | | General and administrative | 38 | | | 38 | | | 33 | |
| Transaction and integration costs | Transaction and integration costs | 7 | | | 9 | | | 3 | | Transaction and integration costs | 7 | | | 7 | | | 9 | |
| Development costs | Development costs | 6 | | | 5 | | | 5 | | Development costs | 2 | | | 6 | | | 5 | |
| Total operating costs and expenses | Total operating costs and expenses | 1,017 | | | 865 | | | 806 | | Total operating costs and expenses | 1,010 | | | 1,017 | | | 865 | |
| Gain on sale of business | | Gain on sale of business | 1,292 | | | — | | | — | |
| Operating Income | Operating Income | 269 | | | 334 | | | 226 | | Operating Income | 1,472 | | | 269 | | | 334 | |
| Other Income (Expense) | Other Income (Expense) | | | | | | Other Income (Expense) | | | | | |
| Equity in earnings of unconsolidated affiliates | Equity in earnings of unconsolidated affiliates | 32 | | | 7 | | | 83 | | Equity in earnings of unconsolidated affiliates | 29 | | | 32 | | | 7 | |
| Impairment loss on investment | Impairment loss on investment | — | | | (8) | | | — | | Impairment loss on investment | — | | | — | | | (8) | |
| Gain on sale of unconsolidated affiliate | Gain on sale of unconsolidated affiliate | — | | | 49 | | | — | | Gain on sale of unconsolidated affiliate | — | | | — | | | 49 | |
| Other income, net | Other income, net | 3 | | | 4 | | | 9 | | Other income, net | 17 | | | 3 | | | 4 | |
| Loss on debt extinguishment | Loss on debt extinguishment | (53) | | | (24) | | | (16) | | Loss on debt extinguishment | (2) | | | (53) | | | (24) | |
| Derivative interest income (expense) | 53 | | | 4 | | | (65) | | |
| Derivative interest income | | Derivative interest income | 100 | | | 53 | | | (38) | |
| Other interest expense | Other interest expense | (365) | | | (418) | | | (338) | | Other interest expense | (332) | | | (365) | | | (376) | |
| Total other expense, net | Total other expense, net | (330) | | | (386) | | | (327) | | Total other expense, net | (188) | | | (330) | | | (386) | |
| Loss Before Income Taxes | (61) | | | (52) | | | (101) | | |
| Income (Loss) Before Income Taxes | | Income (Loss) Before Income Taxes | 1,284 | | | (61) | | | (52) | |
| Income tax expense | Income tax expense | 2 | | | — | | | — | | Income tax expense | 2 | | | 2 | | | — | |
| Net Loss | Net Loss | (63) | | | (52) | | | (101) | | Net Loss | 1,282 | | | (63) | | | (52) | |
| Less: Net loss attributable to noncontrolling interests | (173) | | | (113) | | | (71) | | |
| Net Income (Loss) Attributable to Clearway Energy LLC | $ | 110 | | | $ | 61 | | | $ | (30) | | |
| Less: Net loss attributable to noncontrolling interests and redeemable interests | | Less: Net loss attributable to noncontrolling interests and redeemable interests | (106) | | | (173) | | | (113) | |
| Net Income Attributable to Clearway Energy LLC | | Net Income Attributable to Clearway Energy LLC | $ | 1,388 | | | $ | 110 | | | $ | 61 | |
| | | Year ended December 31, | | Year ended December 31, |
| Business metrics: | Business metrics: | 2021 | | 2020 | | 2019 | Business metrics: | 2022 | | 2021 | | 2020 |
Solar MWh generated/sold (in thousands) (a) | | Solar MWh generated/sold (in thousands) (a) | 4,991 | | | 3,585 | | | 1,894 | |
Wind MWh generated/sold (in thousands) (a) | | Wind MWh generated/sold (in thousands) (a) | 9,343 | | | 7,728 | | | 5,566 | |
Renewables MWh generated/sold (in thousands) (a) | Renewables MWh generated/sold (in thousands) (a) | 11,313 | | | 7,460 | | | 6,584 | | Renewables MWh generated/sold (in thousands) (a) | 14,334 | | | 11,313 | | | 7,460 | |
| Thermal MWt sold (in thousands) | 2,035 | | | 1,927 | | | 2,153 | | |
| Thermal MWh sold (in thousands) | 59 | | | 68 | | | 176 | | |
Conventional MWh generated (in thousands) (a)(b) | 1,108 | | | 1,475 | | | 1,095 | | |
Thermal MWt sold (in thousands) (b) | | Thermal MWt sold (in thousands) (b) | 835 | | | 2,035 | | | 1,927 | |
Thermal MWh sold (in thousands) (b) | | Thermal MWh sold (in thousands) (b) | 19 | | | 59 | | | 68 | |
Conventional MWh generated (in thousands) (a)(c) | | Conventional MWh generated (in thousands) (a)(c) | 1,236 | | | 1,108 | | | 1,475 | |
| Conventional equivalent availability factor | Conventional equivalent availability factor | 94.7 | % | | 94.9 | % | | 94.9 | % | Conventional equivalent availability factor | 92.2 | % | | 94.7 | % | | 94.9 | % |
(a) Volumes do not include the MWh generated/sold by the Company'sCompany’s equity method investments.
(b)On May 1, 2022, the Company completed the sale of 100% of its interests in the Thermal Business to KKR.
(c) Volumes generated are not sold as the Conventional facilities sell capacity rather than energy.
Management'sManagement’s discussion of the results of operations for the years ended December 31, 20212022 and 20202021
Operating Revenues
Operating revenues increaseddecreased by $87$96 million for the year ended December 31, 2021,2022, compared to the same period in 2020,2021, due to a combination of the drivers summarized in the table below:
| | | | | | | | |
| | (In millions) |
| Renewables Segment | Increase for solar acquisitions due to the 2021 acquisitions of the Utah Solar Portfolio and Agua Caliente and the 2022 acquisition of Mililani I, slightly offset by the 2022 disposition of Kawailoa. | $ | 88 | |
| Increase for wind acquisitions due to the 2021 acquisitions of Mt. Storm, Mesquite Star, Rattlesnake, LangfordSky and Rosamond Central,Black Rock and the consolidation2022 acquisition of the DGPV investments as well as higherCapistrano Wind Portfolio, along with the 2021 repowering of the Pinnacle wind production at Alta, partially offset by $50 million ofproject. | 48 | |
| Favorable impact from the loss in February 2021 related to net settlements of obligations for wind facilities that were unable to produce the required output during extreme weather conditions in Texas in February 2021Texas. | $50 | |
| Increase primarily driven by higher average realized prices at the wind facilities. | 217 4 | |
| Decrease primarily driven by lower wind generation. | (7) | |
| Thermal Segment | IncreaseDecrease primarily driven by higher volumes and higher gas prices passed through to customers, partially offset by a sales-type lease recognized in September 2020the sale of the Thermal Business on May 1, 2022. | 10 (130) | |
| Conventional Segment | IncreaseDecrease primarily due to improved availabilitydriven by forced outages at the California natural gas portfolioEl Segundo and Walnut Creek facilities in 2022, resulting in lower capacity revenue. | 3 (23) | |
Mark-to-market economic hedging activitieshedges | Increase in unrealized losses fromdue to changes in the fair value of commodity contracts, primarily driven by the acquisitionsacquisition of Mesquite StarSky in 2021 and Mt. Storm, andmark-to-market losses of the Langford commodity contract, which previously qualified for the NPNS exception. | (76) | |
| Increase in unrealized losses due to increases in forward commoditypower prices in the ERCOT and PJM markets. | (87)(19) | |
| Contract amortization | Increase primarily driven by amortization of the intangible assetassets for power purchase agreement in connection withPPAs related to the 2021 acquisitions of Agua Caliente and the Utah Solar Portfolio and the 2022 acquisition of Agua Calientethe Capistrano Wind Portfolio. | (56)(31) | |
| | $ | 87 (96) | |
Cost of Fuels
Cost of fuels decreased by $46 million during the year ended December 31, 2022, compared to the same period in 2021, primarily due to the sale of the Thermal Business on May 1, 2022, as further described in Item 15 — Note 3, Acquisitions and Dispositions.
Operations and Maintenance Expense
Operations and maintenance expense increased by $60$16 million during the year ended December 31, 20212022, compared to the same period in 2020, primarily from the acquisition of solar and wind projects during the second half of 2020 and the first half of 2021, as well as the consolidationdue to a combination of the DGPV investments on November 2, 2020.drivers summarized in the table below:
| | | | | | | | |
| | (In millions) |
| Renewables Segment | Increase for wind acquisitions due to the 2021 acquisitions of Mt Storm, Mesquite Sky and Black Rock and the 2022 acquisition of the Capistrano Wind Portfolio. | $ | 30 | |
| Increase for solar acquisitions due to the 2021 acquisition of the Utah Solar Portfolio and the 2022 acquisition of Mililani I. | 14 | |
| Increase primarily driven by timing of maintenance activities, as well as increasing material costs largely at the solar and wind facilities. | 6 | |
| Conventional Segment | Increase due to the forced outages at El Segundo and Walnut Creek primarily in the third quarter of 2022. | 5 | |
| Thermal Segment | Decrease primarily driven by the sale of the Thermal Business on May 1, 2022. | (39) | |
| | $ | 16 | |
Other Costs of Operations Expense
Other costs of operations expense, which primarily consists of insurance and property taxes, increased by $23$14 million during the year ended December 31, 2021,2022, compared to the same period in 2020. This was largely2021, primarily due an increase in property taxes due to a netthe acquisitions of the Utah Solar Portfolio, Mesquite Sky and Black Rock in 2021 and the acquisition of the Capistrano Wind Portfolio in 2022, as well as an increase in property taxes at certain wind projects.
Impairment Losses
The Company recorded impairment losses of $16 million and $6 million for the years ended December 31, 2022 and 2021, respectively, related to certain projects in the Renewables segment primarily fromas further described in Item 15— Note 9, Asset Impairments.
Gain on Sale of Business
On May 1, 2022, the acquisitionCompany completed the sale of solar and wind projects during the second half100% of 2020 and the first half of 2021, in addition to refunds of property taxes received in 2020.
Depreciation, Amortization and Accretion
Depreciation, amortization and accretion expense increased by $81 million during the year ended December 31, 2021, compared to the same period in 2020, primarily due to a $90 million increase in the Renewables segment, offset slightly by a $9 million decreaseits interests in the Thermal segment, asBusiness to KKR resulting in a resultgain on sale of the Thermal Business assets being reclassified to held for sale in the fourth quarterbusiness of 2021,approximately $1.29 billion, as further described in Item 15 — Note 3, Acquisitions and Dispositions. The increase in the Renewables segment was driven by the acquisition of solar and wind projects
Other Income, Net
Other income, net increased $14 million during the second half of 2020 and the first half of 2021, as well as the consolidation of the DGPV investments on November 2, 2020, resulting in a cumulative increase of $65 million. In addition, approximately $34 million of accelerated depreciation was recorded in 2021, related to the repowering of the Pinnacle wind facility, which is an increase of $25 millionyear ended December 31, 2022, compared to the same period in 2020.2021, primarily due to higher interest income earned on larger cash balances with investments in money market and time deposit accounts.
Impairment LossesLoss on Debt Extinguishment
The Company recorded impairment lossesloss on debt extinguishment of $6$2 million and $24 million, forduring the yearsyear ended December 31, 2021 and 2020, respectively, primarily2022, which reflects the write-off of previously deferred finance costs related to several wind projects within the Renewables segment,Laredo Ridge, Tapestry Wind LLC and Viento Funding II, LLC, as further described in Item 15 — Note 9,10, Asset ImpairmentsLong-term Debt..
General and Administrative Expenses
General and administrative expenses increased by $5 million during the year ended December 31, 2021 compared to the same period in 2020, primarily due to an increase in net MSA fees charged by CEG, personnel costs and various consulting fees.
Equity in Earnings of Unconsolidated Affiliates
Equity in earnings of unconsolidated affiliates increased by $25 million during the year ended December 31, 2021 compared to the same period in 2020, primarily driven by increased earnings from Desert Sunlight and Avenal in 2021, the acquisition of Mesquite Star on September 1, 2020, which had losses in 2020, and the consolidation of the DGPV investments on November 2, 2020, which had losses in 2020. These increases were partially offset by theabsence of equity in earnings for Agua Caliente, which was consolidated due to the acquisition of an additional interest in February 2021, and the sale of the interests in RPV Holdco in May 2020, which had earnings in 2020.
Impairment Loss on Investment
The Company recorded an $8 million impairment loss during the year ended December 31, 2020 related to San Juan Mesa, an equity method investment within the Renewables segment, as further described in Item 15 — Note 9, Asset Impairments.
Gain on Sale of Unconsolidated Affiliate
On May 14, 2020, the Company sold its interests in RPV Holdco to a third-party, which resulted in a gain on sale of investment of approximately $49 million, as further described in Item 15 — Note 3, Acquisition and Dispositions.
Loss on Debt Extinguishment
The Company recorded loss on debt extinguishment of $53 million during the year ended December 31, 2021, primarily driven by the write-off of previously deferred finance costs and payment of premiums related to the redemption of the 2026 Senior Notes and the 2025 Senior Notes in 2021, as further described in Item 15 — Note 10, Long-term Debt.
The Company recorded loss on debt extinguishment of $24Interest Expense
Interest expense decreased by $80 million during the year ended December 31, 2020, which reflects the write-off of previously deferred debt issuance costs, primarily related to the repayment of debt and related refinancing activities in the Renewables segment, as further described in Item 15 — Note 10, Long-term Debt.
Interest Expense
Interest expense decreased by $102 million during the year ended December 31, 20212022, compared to the same period in 20202021 primarily due to:
| | | | | |
| (In millions) |
| Change in fair value of interest rate swaps due to higher interest rates | $ | (122)(47) | |
IncreaseDecrease in interest expense due to a net increase in project leveldecreased principal balances of project-level debt primarily related to acquisitions in the Renewables segment | 16 (20) | |
IncreaseDecrease in Corporate interest expense due to additional issuancesthe sale of the 2028 Senior Notes inThermal Business on May 2020, 2031 Senior Notes in March 2021 and 2032 Senior Notes in October 2021, as well as an increase1, 2022 | (12) | |
| Decrease in interest expense due to decreased principal balances of Corporate debt, which includes repayment of the outstanding borrowings under the Bridge Loan Agreement and the revolving credit facility on May 3, 2022 | (2) | |
Amortization of deferred financing costs related to the intercompany note between Clearway Operating LLC and Clearway, Inc.; partially offset byBridge Loan that was entered into during the repurchasesfourth quarter of the 2025 Senior Notes in March 2021 and 2026 Senior Notespaid in October 2021full on May 3, 2022 | 41 | |
| $ | (102)(80) | |
| |
Income Tax Expense
DuringFor the year ended December 31, 2022, the Company recorded income tax expense of $2 million on pretax income of $1,283 million. For the same period in 2021, the Company recorded an income tax expense of $2 million on pretax loss of $61 million. The Company is classified as a partnership for federal and state income tax purposes. Therefore, federal and most state income taxes are assessed at the partner level. The franchise tax imposed by the state of Texas, however, is being assessed at the level of certain project subsidiaries of the Company, and therefore reflected as an income tax expense of the Company.
The Company is subject to examination by taxing authorities for income tax returns filed in the U.S. federal and various state jurisdictions. All tax returns filed by the Company for the year ended December 31, 2013 and forward remain subject to audit.
Net Loss Attributable to Noncontrolling Interests and Redeemable Noncontrolling Interests
For the year ended December 31, 2022, the Company had a net loss of $106 million attributable to noncontrolling interests and redeemable noncontrolling interests comprised of the following:
| | | | | | | | |
| | (In millions) |
| Losses attributable to tax equity financing arrangements and the application of HLBV | | $ | (87) | |
| Loss attributable to third-party partnerships | | (19) | |
| | |
| | |
| | $ | (106) | |
For the year ended December 31, 2021, the Company had a net loss of $173 million attributable to noncontrolling interests and redeemable noncontrolling interests comprised of the following:
| | | | | | | | |
| | (In millions) |
| Losses attributable to tax equity financing arrangements and the application of HLBV | | $ | (174) | |
Losses attributable to CEG'sCEG’s interest in partnerships | | (3) | |
| Income attributable to third-party partnerships | | 4 | |
| | |
| | |
| | $ | (173) | |
For the year ended December 31, 2020, the Company had a loss of $113 million attributable to noncontrolling interests and redeemable interests comprised of the following:
| | | | | | | | |
| | (In millions) |
Losses attributable to tax equity financing arrangements and the application of HLBV | | $ | (135) | |
Income attributable to third-party partnerships | | 13 | |
Income attributable to CEG's interest in partnerships | | 9 | |
| | $ | (113) | |
Liquidity and Capital Resources
The Company'sCompany’s principal liquidity requirements are to meet its financial commitments, finance current operations, fund capital expenditures, including acquisitions from time to time, service debt and pay distributions. As a normal part of the Company'sCompany’s business, depending on market conditions, the Company will from time to time consider opportunities to repay, redeem, repurchase or refinance its indebtedness. Changes in the Company'sCompany’s operating plans, lower than anticipated sales, increased expenses, acquisitions or other events may cause the Company to seek additional debt or equity financing in future periods. There can be no guarantee that financing will be available on acceptable terms or at all. Debt financing, if available, could impose additional cash payment obligations and additional covenants and operating restrictions.
Current Liquidity Position
As of December 31, 20212022 and 2020,2021, the Company'sCompany’s liquidity was approximately $821 million$1.37 billion and $894$821 million, respectively, comprised of cash, restricted cash and availability under the Company'sCompany’s revolving credit facility.
| | | As of December 31, | | As of December 31, |
| | 2021 | | 2020 | | 2022 | | 2021 |
| | (In millions) | | (In millions) |
| Cash and cash equivalents: | Cash and cash equivalents: | | | | Cash and cash equivalents: | | | |
| Clearway Energy LLC, excluding subsidiaries | Clearway Energy LLC, excluding subsidiaries | $ | 33 | | | $ | 119 | | Clearway Energy LLC, excluding subsidiaries | $ | 536 | | | $ | 33 | |
| Subsidiaries | Subsidiaries | 146 | | | 149 | | Subsidiaries | 121 | | | 146 | |
| Restricted cash: | Restricted cash: | | Restricted cash: | |
| Operating accounts | Operating accounts | 246 | | | 73 | | Operating accounts | 109 | | | 246 | |
| Reserves, including debt service, distributions, performance obligations and other reserves | Reserves, including debt service, distributions, performance obligations and other reserves | 229 | | | 124 | | Reserves, including debt service, distributions, performance obligations and other reserves | 230 | | | 229 | |
| Total cash, cash equivalents and restricted cash | Total cash, cash equivalents and restricted cash | $ | 654 | | | $ | 465 | | Total cash, cash equivalents and restricted cash | 996 | | | 654 | |
| Revolving credit facility availability | Revolving credit facility availability | 167 | | | 429 | | Revolving credit facility availability | 370 | | | 167 | |
| Total liquidity | Total liquidity | $ | 821 | | | $ | 894 | | Total liquidity | $ | 1,366 | | | $ | 821 | |
|
The Company'sCompany’s liquidity includes $475$339 million and $197$475 million of restricted cash balances as of December 31, 20212022 and 20202021, respectively. Restricted cash consists primarily of funds to satisfy the requirements of certain debt arrangements and funds held within the Company'sCompany’s projects that are restricted in their use.As of December 31, 2021,2022, these restricted funds were comprised of $246$109 million designated to fund operating expenses, approximately $34$55 million designated for current debt service payments, and $131and$105 million restricted for reserves including debt service, performance obligations and other reserves, as well as capital expenditures. The remaining $64$70 million is held in distribution reserve accounts.
As of December 31, 2021,2022, the Company had $245 million ofno outstanding borrowings under the revolving credit facility and $83$125 million in letters of credit outstanding. During the year ended December 31, 2021,2022, the Company borrowed $622$80 million under the revolving credit facility, and subsequently repaid $377$325 million, utilizing cash$305 million of which was repaid on hand andMay 3, 2022, utilizing the proceeds received from the issuanceThermal Disposition. The facility, which the Company expects to refinance prior to its expiration in April 2023, will continue to be used for general corporate purposes including financing of the 2031 Senior Notes.future acquisitions and posting letters of credit.
Management believes that the Company'sCompany’s liquidity position, cash flows from operations and availability under its revolving credit facility will be adequate to meet the Company'sCompany’s financial commitments; debt service obligations; growth, operating and maintenance capital expenditures; and to fund distributions to Clearway, Inc. and CEG. Management continues to regularly monitor the Company'sCompany’s ability to finance the needs of its operating, financing and investing activity within the dictates of prudent balance sheet management.
Credit Ratings
Credit rating agencies rate a firm'sfirm’s public debt securities. These ratings are utilized by the debt markets in evaluating a firm'sfirm’s credit risk. Ratings influence the price paid to issue new debt securities by indicating to the market the Company'sCompany’s ability to pay principal, interest and preferred dividends. Rating agencies evaluate a firm'sfirm’s industry, cash flow, leverage, liquidity and hedge profile, among other factors, in their credit analysis of a firm'sfirm’s credit risk. As of December 31, 2021,2022, the Company'sCompany’s 2028 Senior Notes, 2031 Senior Notes and 2032 Senior Notes are rated BB by S&P and Ba2 by Moody's.Moody’s.
Sources of Liquidity
The Company'sCompany’s principal sources of liquidity include cash on hand, cash generated from operations, proceeds from sales of assets, borrowings under new and existing financing arrangements and the issuance of additional equity and debt securities by Clearway, Inc. or the Company as appropriate given market conditions. As described in Item 15 — Note 10, Long-term Debt, the Company'sCompany’s financing arrangements consist of corporate level debt, which includes Senior Notes, intercompany borrowings with Clearway, Inc., and the revolving credit facility, the ATM Programs,Program, and project-level financings for its various assets.
Thermal Disposition
On October 22, 2021, Clearway Energy Operating LLC entered into a binding agreement to sellMay 1, 2022, the Company completed the sale of 100% of its interests in the Thermal Business to KKR for total consideration of $1.9 billion, subject to customary closing adjustments. Based on current estimates, the Company expects total net cash proceeds of approximately $1.35$1.46 billion, after the assumptioninclusive of project level debt, estimated taxes and obligations owed,working capital adjustments, which excludes approximately $18 million in transaction expenses and capital expenditures required to be funded pursuant tothat were incurred in connection with the terms and conditions of the definitive agreement. The closing of the transaction is subject to various customary closing conditions, approvals and consents and is expected to close in the first half of 2022.
Revolving Credit Facility
The Company has a total of $167 million available under the revolving credit facility as of December 31, 2021. 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, that provides for a term loan facility in an aggregate principal amount of $335 million that will mature no later than November 29, 2022. The Company intends to use proceeds from the Thermal Disposition to repay the outstanding principal balance of the term loans under the Bridge Loan Agreement. The borrowings under the Bridge Loan Facility were used to acquire the Utah Solar Portfolio on December 1, 2021, as described below.
2032 Senior Notes
On October 1, 2021, Clearway Energy Operating LLC completed the sale of $350 million of senior unsecured notes due 2032, or the 2032 Senior Notes. The 2032 Senior Notes bear interest at 3.750% and mature on Januarydisposition. See Item 15 2032. Interest on the 2032 Senior Notes is payable semi-annually on January 15 and July 15 of each year. The 2032 Senior Notes are unsecured obligations of Clearway Energy Operating LLC and are guaranteed by Clearway Energy LLC and by certain of Clearway Energy Operating LLC's wholly-owned current and future subsidiaries. The net proceeds from the 2032 Senior Notes were used, together with existing corporate liquidity, to repurchase the 2026 Senior Notes.
Pinnacle Repowering Partnership Holdco LLC Financing
On March 10, 2021, the Company entered into a financing agreement for non-recourse debt for a total commitment of $126 million related to the repowering of the Pinnacle wind project. The debt consists of a construction loan at an interest rate of LIBOR plus 1.00%. The company's initial borrowings of $79 million were utilized to repay $53 million of the outstanding balance under the Tapestry Wind LLC financing agreement, which related to the Pinnacle wind project, and to reimburse Clearway Renew LLC for equipment purchases and pay vendor invoices and fees. On December 15, 2021, the Company repaid the outstanding principal amount of $117 million utilizing existing corporate liquidity, along with proceeds from tax equity.
2031 Senior Notes
On March 9, 2021, Clearway Energy Operating LLC completed the sale of $925 million of senior unsecured notes due 2031, or the 2031 Senior Notes. The 2031 Senior Notes bear interest at 3.750% and mature on February 15, 2031. Interest on the 2031 Senior Notes is payable semi-annually on February 15 and August 15 of each year. The 2031 Senior Notes are unsecured obligations of Clearway Energy Operating LLC and are guaranteed by Clearway Energy LLC and by certain of Clearway Energy Operating LLC's wholly-owned current and future subsidiaries. The net proceeds from the 2031 Senior Notes were used to repurchase the 2025 Senior Notes, as well as to repay amounts outstanding under the Company's revolving credit facility and for general corporate purposes.
OahuAcquisitions and Kawailoa Hawaii Refundable Tax Credits
In 2020, the members of the partnerships holding the Oahu Solar and Kawailoa Solar projects submitted applications to the state of Hawaii Dispositions,for refundable tax credits based on the cost of construction of the projects. In April 2021, the members of the partnerships contributed their respective portions of the tax credits in the amount of $49 million to the Oahu Solar and Kawailoa project companies, which was recorded to restricted cash on the Company's consolidated balance sheet with an offsetting adjustment to noncontrolling interests. In accordance with the projects' related agreements, the cash is held in a restricted account and utilized to offset invoiced amounts under the projects' PPAs. As of December 31, 2021, $20 million of the $49 million has been utilized to offset invoiced amounts under the projects' PPAs.further discussion.
Uses of Liquidity
The Company'sCompany’s requirements for liquidity and capital resources, other than for operating its facilities, are categorized as: (i) debt service obligations, as described more fully in Item 15 — Note 10, Long-term Debt; (ii) capital expenditures; (iii) off-balance sheet arrangements; (iv) acquisitions and investments;investments, as described more fully in Item 15 —Note 3, Acquisitions and Dispositions; and (v) distributions.
Debt Service Obligations
Principal payments on debt as of December 31, 2021,2022, are due in the following periods:
| | Description | Description | 2022 | | 2023 | | 2024 | | 2025 | | 2026 | | There- after | | Total | | Description | 2023 | | 2024 | | 2025 | | 2026 | | 2027 | | There- after | | Total | |
| | (In millions) | | | (In millions) | |
| | Corporate-level debt: | | Corporate-level debt: | | |
| Intercompany Note with Clearway Energy, Inc. | Intercompany Note with Clearway Energy, Inc. | $ | 1 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | 1 | | | Intercompany Note with Clearway Energy, Inc. | $ | 2 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | 2 | | |
| | Clearway Energy Operating LLC Senior Notes, due 2028 | Clearway Energy Operating LLC Senior Notes, due 2028 | — | | | — | | | — | | | — | | | — | | | 850 | | | 850 | | | Clearway Energy Operating LLC Senior Notes, due 2028 | — | | | — | | | — | | | — | | | — | | | 850 | | | 850 | | |
| Clearway Energy Operating LLC Senior Notes, due 2031 | Clearway Energy Operating LLC Senior Notes, due 2031 | — | | | — | | | — | | | — | | | — | | | 925 | | | 925 | | | Clearway Energy Operating LLC Senior Notes, due 2031 | — | | | — | | | — | | | — | | | — | | | 925 | | | 925 | | |
| Clearway Energy Operating LLC Senior Notes, due 2032 | Clearway Energy Operating LLC Senior Notes, due 2032 | — | | | — | | | — | | | — | | | — | | | 350 | | | 350 | | | Clearway Energy Operating LLC Senior Notes, due 2032 | — | | | — | | | — | | | — | | | — | | | 350 | | | 350 | | |
| Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 | — | | | 245 | | | — | | | — | | | — | | | — | | | 245 | | | |
| Bridge Loan, due 2022 | 335 | | | — | | | — | | | — | | | — | | | — | | | 335 | | | |
| | Total Corporate-level debt | Total Corporate-level debt | 336 | | | 245 | | | — | | | — | | | — | | | 2,125 | | | 2,706 | | | Total Corporate-level debt | 2 | | | — | | | — | | | — | | | — | | | 2,125 | | | 2,127 | | |
| Project-level debt: | Project-level debt: | | | Project-level debt: | | |
| Agua Caliente Solar LLC, due 2037 | Agua Caliente Solar LLC, due 2037 | 35 | | | 37 | | | 38 | | | 39 | | | 40 | | | 495 | | | 684 | | | Agua Caliente Solar LLC, due 2037 | 37 | | | 38 | | | 39 | | | 40 | | | 41 | | | 454 | | | 649 | | |
| Alta Wind Asset Management LLC | 1 | | | 1 | | | 1 | | | 1 | | | 1 | | | 8 | | | 13 | | | |
| Alta Wind Asset Management LLC, due 2031 | | Alta Wind Asset Management LLC, due 2031 | 1 | | | 1 | | | 1 | | | 1 | | | 1 | | | 7 | | | 12 | | |
| Alta Wind I-V lease financing arrangements, due 2034 and 2035 | Alta Wind I-V lease financing arrangements, due 2034 and 2035 | 47 | | | 49 | | | 51 | | | 54 | | | 55 | | | 500 | | | 756 | | | Alta Wind I-V lease financing arrangements, due 2034 and 2035 | 49 | | | 51 | | | 54 | | | 55 | | | 57 | | | 443 | | | 709 | | |
| Alta Wind Realty Investments LLC, due 2031 | Alta Wind Realty Investments LLC, due 2031 | 2 | | | 2 | | | 2 | | | 2 | | | 3 | | | 13 | | | 24 | | | Alta Wind Realty Investments LLC, due 2031 | 2 | | | 2 | | | 2 | | | 3 | | | 3 | | | 10 | | | 22 | | |
| | Borrego, due 2024 and 2038 | Borrego, due 2024 and 2038 | 3 | | | 3 | | | 3 | | | 3 | | | 3 | | | 39 | | | 54 | | | Borrego, due 2024 and 2038 | 3 | | | 3 | | | 2 | | | 3 | | | 3 | | | 37 | | | 51 | | |
| Buckthorn Solar, due 2025 | Buckthorn Solar, due 2025 | 3 | | | 4 | | | 4 | | | 112 | | | — | | | — | | | 123 | | | Buckthorn Solar, due 2025 | 3 | | | 4 | | | 112 | | | — | | | — | | | — | | | 119 | | |
| Carlsbad Holdco, due 2038 | 7 | | | 2 | | | 3 | | | 3 | | | 9 | | | 181 | | | 205 | | | |
| Capistrano Wind Portfolio, due 2029 and 2031 | | Capistrano Wind Portfolio, due 2029 and 2031 | 19 | | | 20 | | | 21 | | | 22 | | | 22 | | | 52 | | | 156 | | |
| Carlsbad Energy Holdings LLC, due 2027 | Carlsbad Energy Holdings LLC, due 2027 | 21 | | | 22 | | | 23 | | | 25 | | | 26 | | | 19 | | | 136 | | | Carlsbad Energy Holdings LLC, due 2027 | 22 | | | 23 | | | 25 | | | 26 | | | 19 | | | — | | | 115 | | |
| | Carlsbad Energy Holdings LLC, due 2038 | Carlsbad Energy Holdings LLC, due 2038 | — | | | — | | | — | | | — | | | — | | | 407 | | | 407 | | | Carlsbad Energy Holdings LLC, due 2038 | — | | | — | | | — | | | — | | | 7 | | | 400 | | | 407 | | |
| Carlsbad Holdco, LLC, due 2038 | | Carlsbad Holdco, LLC, due 2038 | 2 | | | 2 | | | 3 | | | 9 | | | 11 | | | 170 | | | 197 | | |
| CVSR, due 2037 | CVSR, due 2037 | 25 | | | 26 | | | 28 | | | 30 | | | 32 | | | 511 | | | 652 | | | CVSR, due 2037 | 26 | | | 28 | | | 30 | | | 32 | | | 35 | | | 476 | | | 627 | | |
| CVSR Holdco Notes, due 2037 | CVSR Holdco Notes, due 2037 | 9 | | | 9 | | | 9 | | | 9 | | | 9 | | | 124 | | | 169 | | | CVSR Holdco Notes, due 2037 | 9 | | | 9 | | | 9 | | | 9 | | | 9 | | | 115 | | | 160 | | |
| DG-CS Master Borrower LLC, due 2040 | DG-CS Master Borrower LLC, due 2040 | 28 | | | 28 | | | 29 | | | 30 | | | 30 | | | 296 | | | 441 | | | DG-CS Master Borrower LLC, due 2040 | 28 | | | 29 | | | 30 | | | 30 | | | 28 | | | 268 | | | 413 | | |
Duquesne, due 2059 (a) | — | | | — | | | — | | | — | | | — | | | 95 | | | 95 | | | |
| El Segundo Energy Center, due 2023 | 63 | | | 130 | | | — | | | — | | | — | | | — | | | 193 | | | |
Energy Center Minneapolis Series D, E, F, G, H Notes, due 2025-2037 (a) | — | | | — | | | — | | | 4 | | | 15 | | | 309 | | | 328 | | | |
| Kawailoa Solar Portfolio LLC, due 2026 | 2 | | | 2 | | | 2 | | | 3 | | | 69 | | | — | | | 78 | | | |
| Laredo Ridge, due 2028 | 7 | | | 7 | | | 9 | | | 11 | | | 12 | | | 26 | | | 72 | | | |
| Marsh Landing, due 2023 | Marsh Landing, due 2023 | 65 | | | 19 | | | — | | | — | | | — | | | — | | | 84 | | | Marsh Landing, due 2023 | 19 | | | — | | | — | | | — | | | — | | | — | | | 19 | | |
| Mililani I, due 2027 | | Mililani I, due 2027 | 1 | | | 1 | | | 2 | | | 1 | | | 42 | | | — | | | 47 | | |
| NIMH Solar, due 2024 | NIMH Solar, due 2024 | 14 | | | 14 | | | 148 | | | — | | | — | | | — | | | 176 | | | NIMH Solar, due 2024 | 15 | | | 148 | | | — | | | — | | | — | | | — | | | 163 | | |
| Oahu Solar Holdings LLC, due 2026 | Oahu Solar Holdings LLC, due 2026 | 3 | | | 3 | | | 3 | | | 3 | | | 74 | | | — | | | 86 | | | Oahu Solar Holdings LLC, due 2026 | 2 | | | 3 | | | 3 | | | 75 | | | — | | | — | | | 83 | | |
| Rosie Class B, due 2027 | 2 | | | 2 | | | 3 | | | 3 | | | 3 | | | 65 | | | 78 | | | |
| | Tapestry, due 2031 | 6 | | | 6 | | | 8 | | | 8 | | | 9 | | | 48 | | | 85 | | | |
| Rosie Class B LLC, due 2027 | | Rosie Class B LLC, due 2027 | 2 | | | 3 | | | 3 | | | 3 | | | 65 | | | — | | | 76 | | |
| Utah Solar Holdings, due 2036 | Utah Solar Holdings, due 2036 | 16 | | | 15 | | | 14 | | | 14 | | | 16 | | | 198 | | | 273 | | | Utah Solar Holdings, due 2036 | 15 | | | 15 | | | 14 | | | 16 | | | 16 | | | 181 | | | 257 | | |
| Viento Funding II, LLC, due 2029 | | Viento Funding II, LLC, due 2029 | 8 | | | 16 | | | 17 | | | 20 | | | 24 | | | 99 | | | 184 | | |
Waiawa, due 2023 (a) | | Waiawa, due 2023 (a) | 97 | | | — | | | — | | | — | | | — | | | — | | | 97 | | |
| Walnut Creek, due 2023 | Walnut Creek, due 2023 | 55 | | | 19 | | | — | | | — | | | — | | | — | | | 74 | | | Walnut Creek, due 2023 | 19 | | | — | | | — | | | — | | | — | | | — | | | 19 | | |
| WCEP Holdings, LLC due 2023 | 4 | | | 26 | | | — | | | — | | | — | | | — | | | 30 | | | |
| WCEP Holdings, LLC, due 2023 | | WCEP Holdings, LLC, due 2023 | 26 | | | — | | | — | | | — | | | — | | | — | | | 26 | | |
| Other | Other | 19 | | | 38 | | | 14 | | | 15 | | | 16 | | | 78 | | | 180 | | | Other | 14 | | | 14 | | | 15 | | | 16 | | | 16 | | | 62 | | | 137 | | |
| Total project-level debt | Total project-level debt | 437 | | | 464 | | | 392 | | | 369 | | | 422 | | | 3,412 | | | 5,496 | | | Total project-level debt | 419 | | | 410 | | | 382 | | | 361 | | | 399 | | | 2,774 | | | 4,745 | | |
| Total debt | Total debt | $ | 773 | | | $ | 709 | | | $ | 392 | | | $ | 369 | | | $ | 422 | | | $ | 5,537 | | | $ | 8,202 | | | Total debt | $ | 421 | | | $ | 410 | | | $ | 382 | | | $ | 361 | | | $ | 399 | | | $ | 4,899 | | | $ | 6,872 | | |
(a)Principal debt payments relate to Thermal BusinessAt December 31, 2022, amount includes $97 million recorded in long-term debt reclassifiedon the Company’s consolidated balance sheet that is due in 2023 and is either being funded through long-term equity contributions or is converting to held for salelong-term debt.
El Segundo Energy Center
On December 15, 2022, the Company repaid the outstanding project-level debt of El Segundo Energy Center in the fourth quarteramount of 2021.approximately $130 million utilizing cash on hand.
Capital Expenditures
The Company'sCompany’s capital spending program is mainly focused on maintenance capital expenditures, consisting of costs to maintain the assets currently operating, such as costs to replace or refurbish assets during routine maintenance, and growth capital expenditures consisting of costs to construct new assets, and costs to complete the construction of assets where construction is in process, and capital expenditures related to acquiring additional thermal customers.process.
For the years ended December 31, 20212022 and 2020,2021, the Company used approximately $151$112 million, and $124$151 million, respectively, to fund capital expenditures, including maintenance capital expenditures of $25 million and $23 million, respectively.for both years. Growth capital expenditures in 2021 include $962022 of $83 million in the Renewables segment $43were funded through construction-related financing. Renewables segment capital expenditures included $34 million incurred in connection with the repowering ofMililani I solar project, $26 million incurred in connection with the PinnacleMesquite Sky wind project, $19$10 million incurred in connection with the Black Rock wind project, $5 million incurred in connection with the Rattlesnake wind project $18 million incurred in connection with the Rosamond Central solar project, $13 million incurred in connection with the Mesquite Star wind project and $3$8 million incurred by other wind and solar projects. ThePrior to the sale of the Thermal Business on May 1, 2022, the Company also incurred $30$4 million of growth capital expenditures in the Thermal and Conventional segmentssegment in connection with various development projects.
The Company estimates $36$35 million of maintenance capital expenditures for 2022, which includes the Thermal segment for all of 2022.2023. These estimates are subject to continuing review and adjustment and actual capital expenditures may vary from these estimates.
Off-Balance Sheet Arrangements
Obligations under Certain Guarantee Contracts
The Company may enter into guarantee arrangements in the normal course of business to facilitate commercial transactions with third parties.
Retained or Contingent Interests
The Company does not have any material retained or contingent interests in assets transferred to an unconsolidated entity.
Obligations Arising Out of a Variable Interest in an Unconsolidated Entity
Variable interest in equity investments — As of December 31, 2021,2022, the Company has several investments with an ownership interest percentage of 50% or less. GenConn is a variable interest entity for which the Company is not the primary beneficiary. The Company'sCompany’s pro-rata share of non-recourse debt held by unconsolidated affiliates was approximately $345$325 million as of December 31, 2021.2022. This indebtedness may restrict the ability of these subsidiaries to issue dividends or distributions to the Company. See also Item 15 — Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities.
Contractual Obligations and Commercial Commitments
In addition to the Company'sCompany’s capital expenditure programs, the Company has a variety of contractual obligations and other commercial commitments that represent prospective cash requirements. The following table summarizes the Company'sCompany’s contractual obligations. See Item 15 — Note 10, Long-term Debt, Note 14, Commitments and Contingencies, and Note 15, Leases, for additional discussion.
| | | By Remaining Maturity at December 31, | | By Remaining Maturity at December 31, |
| | 2021 | | 2020 | | 2022 | | 2021 |
| Contractual Cash Obligations | Contractual Cash Obligations | Under
1 Year | | 1-3 Years | | 3-5 Years | | Over
5 Years | | Total | | Total | Contractual Cash Obligations | Under
1 Year | | 1-3 Years | | 3-5 Years | | Over
5 Years | | Total | | Total |
| | (In millions) | | (In millions) |
Long-term debt (including estimated interest) (a) | Long-term debt (including estimated interest) (a) | $ | 1,108 | | | $ | 1,685 | | | $ | 1,303 | | | $ | 6,701 | | | $ | 10,797 | | | $ | 9,560 | | Long-term debt (including estimated interest) (a) | $ | 710 | | | $ | 1,309 | | | $ | 1,209 | | | $ | 5,635 | | | $ | 8,863 | | | $ | 10,796 | |
Operating leases (b) | Operating leases (b) | 28 | | | 56 | | | 57 | | | 801 | | | 942 | | | 591 | | Operating leases (b) | 28 | | | 60 | | | 63 | | | 831 | | | 982 | | | 942 | |
Fuel purchase and transportation obligations | Fuel purchase and transportation obligations | 7 | | | 1 | | | — | | | — | | | 8 | | | 14 | | Fuel purchase and transportation obligations | — | | | — | | | — | | | — | | | — | | | 8 | |
Other liabilities (c)(b) | Other liabilities (c)(b) | 32 | | | 53 | | | 45 | | | 180 | | | 310 | | | 293 | | Other liabilities (c)(b) | 25 | | | 47 | | | 40 | | | 188 | | | 300 | | | 310 | |
| Total | Total | $ | 1,175 | | | $ | 1,795 | | | $ | 1,405 | | | $ | 7,682 | | | $ | 12,057 | | | $ | 10,458 | | Total | $ | 763 | | | $ | 1,416 | | | $ | 1,312 | | | $ | 6,654 | | | $ | 10,145 | | | $ | 12,056 | |
(a)Remaining maturities ofThese contractual cash obligations were related to the Thermal Business, long-term debt reclassified to held for sale in the fourth quarter of 2021 are $19 million, $40 million, $57 million and $596 million due underwhich was sold on May 1, Year, 1-3 Years, 3-5 Years and Over 5 Years, respectively.2022.
(b)Remaining maturities of Thermal Business operating leases reclassified to held for sale in the fourth quarter of 2021 are $1 million, $2 million, $2 million and $31 million due under 1 Year, 1-3 Years, 3-5 Years and Over 5 Years, respectively.
(c) Includes water right agreements, service and maintenance agreements, and LTSA commitments.
Acquisitions and Investments
The Company intends to acquire generation assets developed and constructed by CEG as well as generation assets from third parties where the Company believes its knowledge of the market and operating expertise provides a competitive advantage, and to utilize such acquisitions as a means to grow its business.
Black RockDaggett 3 Drop Down— — On December 29, 2021,February 17, 2023, the Company, through its indirect subsidiary Lighthouse Renewable Holding Sub LLC,a partnership with a third-party investor, acquired the Class B membership interestsan interest in Black Rock Wind HoldingDaggett TargetCo LLC from Clearway Renew LLC a subsidiary of CEG, for $60 million in cash consideration $37 million of which was paid on December 29, 2021, with the remaining $23 million paid in February 2022 after all remaining turbines were operational. Lighthouse Renewable Holding Sub LLC is a wholly-owned subsidiary of Lighthouse Renewable Holdco LLC, which is a partnership between the Company and a third-party investor. Black Rock Wind Holding$21 million. Daggett TargetCo LLC is the primary beneficiary and consolidates its interest in a tax equity fund, Black RockDaggett TE Holdco LLC, that holds the Black Rock wind project, a 115 MW utility scale wind project located in Mineral County and Grant County, West Virginia. As of December 31, 2021, 70 MWowner of the 115 MW rated capacity were operational, representing fourteenDaggett 3 solar project. Daggett 3 has PPAs with investment-grade counterparties that have a 15-year weighted average contract duration that commence when the project reaches commercial operations, which is expected to occur in the first half of the twenty-three wind turbines, and the remaining 45 MW rated capacity became operational in January 2022.2023. The investmentacquisition was funded with existing sources of liquidity.
Mesquite SkyWaiawa Drop Down — On December 17, 2021,October 3, 2022, the Company, through a partnership with a third-party investor, acquired Waiawa BL Borrower Holdco LLC, the indirect owner, through its indirect subsidiary Lighthouse Renewable Holdco 2 LLC, acquiredownership interests in and consolidation of a tax equity fund, of the Class B membership interests of Mesquite Sky Holding LLCWaiawa solar project, from Clearway Renew LLC for cash consideration of $20 million. Waiawa has a subsidiary of CEG for $61 million20-year PPA with an investment-grade utility that commenced in cash consideration. Lighthouse Renewable Holdco 2 LLC is a partnership between the Company and a third-party investor. Mesquite Sky Holding LLC, through its subsidiary, is the primary beneficiary and consolidates its interest in a tax equity fund, Mesquite Sky TE Holdco LLC, that holds the Mesquite Sky wind project, a 340 MW utility scale wind project located in Callahan County, Texas, which achieved commercial operations in December 2021.January 2023. The investmentacquisition was funded with existing sources of liquidity. As part of the acquisition, the Company assumed the project’s financing agreement, which includes a construction loan that converts to a term loan upon the project reaching substantial completion, which is expected to occur in the first half of 2023, a tax equity bridge loan that will be repaid upon the project reaching substantial completion and a sponsor equity bridge loan that was repaid at acquisition date.
UtahCapistrano Wind Portfolio Acquisition — On December 1, 2021,August 22, 2022, the Company acquired the remaining 50% equity interest in the Utah SolarCapistrano Wind Portfolio from Dominion Solar Projects III, Inc.,Capistrano Wind Partners LLC for approximately $335 million before working capital and purchase price adjustments in the net amount of $5 million, representing total net consideration of $330approximately $239 million. The Utah Solar Portfolio consistsassets within the portfolio sell power under PPAs with investment-grade counterparties that have a weighted average remaining contract duration of seven utility-scale solar farms locatedapproximately 10 years. The acquisition was funded with existing sources of liquidity. As part of the acquisition, the Company assumed non-recourse project-level debt held by the projects in Utah, representing 530 MW of capacity. Borrowings under the Bridge Loan Agreement were used to fund the acquisition.portfolio.
Mt. Storm AcquisitionMililani I Drop Down — On April 23, 2021, the Company acquired 100% of the equity interests in NedPower Mount Storm LLC, or Mt. Storm, from Castleton Commodities International for approximately $96 million before working capital and purchase price adjustments in the net amount of $4 million, representing a total net consideration of $100 million. Mt. Storm is a 264 MW wind project located in Grant County, West Virginia.
Pinnacle Wind Repowering — On February 26, 2021,March 25, 2022, the Company, through an indirect subsidiary, entered into an amendeda partnership agreement with CEG to repower the Pinnacle wind project, a 54 MW wind facility located in Mineral County, West Virginia. On March 10, 2021, the Pinnacle wind projectthird-party investor, acquired equipment from CEG for $21 million in cash consideration. On December 14, 2021, the repowering project reached COD and on December 15, 2021, the Company funded $64 million in existing corporate liquidity, which was utilized in part to repay the Pinnacle Repowering PartnershipMililani BL Borrower Holdco LLC, construction loan, along with proceeds fromthe indirect owner, through its ownership interests in and consolidation of a tax equity.
Agua Caliente Acquisition — On February 3, 2021,equity fund, of the Company acquired an additional 35% equity interest in the Agua CalienteMililani I solar project from NRG Energy, Inc.Clearway Renew LLC for $202cash consideration of $22 million. Agua Caliente isMililani I has a 290 MW solar project located20-year PPA with an investment-grade utility that commenced in Dateland, Arizona in whichJuly 2022. The acquisition was funded with existing sources of liquidity. As part of the acquisition, the Company previously ownedassumed the project’s financing agreement, which includes a 16%construction loan that converted to a term loan on December 7, 2022 upon the project reaching substantial completion, a tax equity interest.bridge loan that was repaid on December 7, 2022 and a sponsor equity bridge loan that was repaid at acquisition date.
RattlesnakeBlack Rock Drop Down — On January 12, 2021, the Company acquired 100% of CEG's equity interest and a third-party investor's minority interest in CWSP Rattlesnake Holding LLC for $132 million in cash consideration. CWSP Rattlesnake Holding LLC indirectly consolidates the Rattlesnake wind project, a 160 MW wind facility located in Adams County, Washington that achieved commercial operations in December 2020. The Company's net capital commitment was $119 million after proceeds from a state sales and use tax refund, which was received in May 2021.
Debt Repurchases
2026 Senior Notes Tender Offer and Redemption —In OctoberFebruary 2022, in connection with the 2021 Black Rock Drop Down, the Company repurchased and redeemedpaid an aggregate principal amount of $350additional $23 million to Clearway Renew, LLC as final funding after all remaining turbines of the 2026 Senior Notes, through the cash tender offer announced on September 24, 2021 and the redemption of the remaining principal amount of $227 million on October 25, 2021. The 2026 Senior Notes repurchased and redeemed in October 2021 were effectuated at a premium of approximately 103% for total consideration of $359 million and, as a result, the Company recorded a loss on extinguishment in the amount of $9 million. The Company recorded an additional $3 million loss on extinguishment to write off the remaining unamortized deferred financing fees related to the 2026 Senior Notes.
2025 Senior Notes Tender Offer and Redemption— In March 2021, the Company repurchased and redeemed an aggregate principal amount of $600 million of the 2025 Senior Notes, through the cash tender offer announced on March 2, 2021 and the redemption of the remaining principal amount of $183 million on March 17, 2021. The 2025 Senior Notes repurchased and redeemed in March 2021 were effectuated at a premium of approximately 106% for total consideration of $636 million and, as a result, the Company recorded a loss on extinguishment in the amount of $36 million. In addition, the Company recorded a $5 million loss on extinguishment to write off the remaining unamortized deferred financing fees related to the 2025 Senior Notes.project became operational.
Cash Distributions to Clearway, Inc. and CEG
The Company intends to distribute to its unit holders in the form of a quarterly distribution all of the CAFD that is generated each quarter less reserves for the prudent conduct of the business, including among others, maintenance capital expenditures to maintain the operating capacity of the assets. Distributions on units 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 distributions will continue to be paid in the foreseeable future.
The following table lists the distributions paid on the Company'sCompany’s Class A, Class B, Class C and Class D units during the year ended December 31, 2021:2022:
| | | Fourth Quarter 2021 | | Third Quarter 2021 | | Second Quarter 2021 | | First Quarter 2021 | | Fourth Quarter 2022 | | Third Quarter 2022 | | Second Quarter 2022 | | First Quarter 2022 |
| Distributions per Class A and Class B units | Distributions per Class A and Class B units | $ | 0.3400 | | | $ | 0.3345 | | | $ | 0.3290 | | | $ | 0.3240 | | Distributions per Class A and Class B units | $ | 0.3672 | | | $ | 0.3604 | | | $ | 0.3536 | | | $ | 0.3468 | |
| Distributions per Class C and Class D units | Distributions per Class C and Class D units | $ | 0.3400 | | | $ | 0.3345 | | | $ | 0.3290 | | | $ | 0.3240 | | Distributions per Class C and Class D units | 0.3672 | | | 0.3604 | | | 0.3536 | | | 0.3468 | |
On February 17, 2022,15, 2023, the Company declared a quarterly distribution on its Class A, Class B, Class C and Class D units of $0.3468$0.3745 per unit payable on March 15, 2022.2023.
Cash Flow Discussion
Year Ended December 31, 20212022 Compared to Year Ended December 31, 20202021
The following table reflects the changes in cash flows for the year ended December 31, 20212022 compared to 2020:2021:
| | | | | | | | | | | | | | | | | |
| Year ended December 31, | 2021 | | 2020 | | Change |
| (In millions) | |
| Net cash provided by operating activities | $ | 701 | | | $ | 545 | | | $ | 156 | |
| Net cash used in investing activities | (865) | | | (62) | | | (803) | |
| Net cash used in financing activities | 367 | | | (432) | | | 799 | |
| | | | | | | | | | | | | | | | | |
| Year ended December 31, | 2022 | | 2021 | | Change |
| (In millions) |
| Net cash provided by operating activities | $ | 797 | | | $ | 701 | | | $ | 96 | |
| Net cash provided by (used in) investing activities | 1,065 | | | (865) | | | 1,930 | |
| Net cash (used in) provided by financing activities | (1,520) | | | 367 | | | (1,887) | |
Net Cash Provided by Operating Activities
Changes to net cash provided by operating activities were driven by:
| | | | | |
| Changes to net cash provided by operating activities were driven by: | (In millions) |
| Increase in operating income adjusted for non-cash items | $ | 14288 | |
| Increase in working capital primarily driven by the timing of accounts receivable collections and payments of accounts payable | 37 27 | |
| Transaction expenses paid on May 1, 2022 in connection with the sale of the Thermal Business | (18) | |
| Decrease in distributions from unconsolidated affiliates | (23)(1) | |
| $ | 15696 | |
Net Cash Used InProvided by (Used In) Investing Activities
Changes to net cash used in investing activities were driven by:
| | | | | |
| Changes to net cash provided by (used) in investing activities were driven by: | (In millions) |
| Proceeds from the sale of the Thermal Business | $ | 1,457 | |
Cash paid for Utah Solar Portfolio, Agua Caliente and Mt. Storm acquisitions, net of cash acquired, in 2021 | $ | (533)533 | |
ChangesDecrease in cash paid for Drop Down assets | (107)158 | |
Proceeds received from the sale of RPV Holdco, Energy Center Dover LLC and Energy Center Smyrna LLC in 2020 | (90) | |
ChangesDecrease in capital expenditures | (27) | |
Change in return of investment from unconsolidated affiliates, net of investments paid | (21)39 | |
| Cash paid to CEG in 2021 for equipment for the Pinnacle wind project repowering | (21)21 | |
Consolidation of DGPV Holdco 3Cash paid to CEG in 20202022 for Capistrano Wind Portfolio | (17)(223) | |
| Decrease in the return of investment from unconsolidated affiliates | (34) | |
| Other | 13 (21) | |
| $ | (803)1,930 | |
Net Cash Used In(Used In) Provided by Financing Activities
Changes in net cash used in financing activities were driven by:
| | | | | |
| Changes in net cash (used in) provided by financing activities were driven by: | (In millions) |
IncreaseDecrease in net contributions from noncontrolling interests and CEG, and noncontrolling interest membersnet of distributions | $ | 720 (907) | |
IncreaseDecrease in net proceeds underfrom the revolving linecredit facility, net of creditpayments | 245 (490) | |
Payment to buy out CEG's noncontrolling interest in Repowering Partnership II LLC on May 11, 2020 | 70 | |
IncreaseDecrease in payments for long-term debt, net of proceeds from issuance of long-term debt, primarily due to issuance of the 2031 and 2032 Senior Notes, Bridge Loan Agreement and the Pinnacle financing agreement in 2021 | (124)(389) | |
DecreaseCash released from escrow distributed to CEG in net proceeds received from equity issuance2022 | (62)(64) | |
| Increase in distributions paid to unit holders in 2022 | (57)(21) | |
| Tax-related distributions in 2022 | (19) | |
| Other | 73 | |
| |
| |
| |
| |
| $ | 799 (1,887) | |
Fair Value of Derivative Instruments
The Company may enter into commodity purchase contracts and other energy-related financial instruments to mitigate variability in earnings due to fluctuations in spot market prices and to hedge fuel requirements at certain generation facilities.prices. In addition, in order to mitigate interest rate risk associated with the issuance of variable rate debt, the Company enters into interest rate swap agreements.
The tables below disclose the activities of non-exchange traded contracts accounted for at fair value in accordance with ASC 820. Specifically, these tables disaggregate realized and unrealized changes in fair value; disaggregate estimated fair values at December 31, 20212022, based on their level within the fair value hierarchy defined in ASC 820; and indicate the maturities of contracts at December 31, 20212022. For a full discussion of the Company'sCompany’s valuation methodology of its contracts, see Derivative Fair Value Measurements in Item 15 — Note 6, Fair Value of Financial Instruments.
| | | | | |
| Derivative Activity ( Losses)/Gains | (In millions) |
Fair value of contracts as of December 31, 20202021 | $ | (172)(236) | |
| Contracts realized or otherwise settled during the period | 39118 | |
| Contracts acquired during the period | (52)24 | |
| Contracts added due to loss of NPNS exception | (22) | |
| Contracts removed during the period | 1 | |
| Changes in fair value | (51)(149) | |
Fair value of contracts as of December 31, 20212022 | $ | (236)(264) | |
| | | Fair value of contracts as of December 31, 2021 | | Fair value of contracts as of December 31, 2022 |
| | Maturity | | Maturity |
| Fair Value Hierarchy Losses | Fair Value Hierarchy Losses | 1 Year or Less | | Greater Than 1 Year to 3 Years | | Greater Than 3 Years to 5 Years | | Greater Than 5 Years | | Total Fair Value | Fair Value Hierarchy Losses | 1 Year or Less | | Greater Than 1 Year to 3 Years | | Greater Than 3 Years to 5 Years | | Greater Than 5 Years | | Total Fair Value |
| | (In millions) | | (In millions) |
| | Level 2 | Level 2 | (22) | | | (16) | | | (18) | | | (1) | | | (57) | | Level 2 | $ | 26 | | | $ | 36 | | | $ | 16 | | | $ | 11 | | | $ | 89 | |
| Level 3 | Level 3 | (24) | | | (47) | | | (36) | | | (72) | | | (179) | | Level 3 | (50) | | | (92) | | | (76) | | | (135) | | | (353) | |
| Total | Total | $ | (46) | | | $ | (63) | | | $ | (54) | | | $ | (73) | | | $ | (236) | | Total | $ | (24) | | | $ | (56) | | | $ | (60) | | | $ | (124) | | | $ | (264) | |
The Company has elected to disclose derivative assets and liabilities on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. As discussed below in Quantitative and Qualitative Disclosures about Market Risk -Commodity Price Risk, the Company measures the sensitivity of the portfolio to potential changes in market prices using VaR, a statistical model which attempts to predict risk of loss based on market price and volatility. The Company's risk management policy places a limit on one-day holding period VaR, which limits the net open position.
Critical Accounting Policies and Estimates
The Company'sCompany’s discussion and analysis of the financial condition and results of operations are based upon the consolidated financial statements, which have been prepared in accordance with GAAP. The preparation of these financial statements and related disclosures in compliance with GAAP requires the application of appropriate technical accounting rules and guidance as well as the use of estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities. The application of these policies necessarily involves judgments regarding future events, including the likelihood of success of particular projects, legal and regulatory challenges and the fair value of certain assets and liabilities. These judgments, in and of themselves, could materially affect the financial statements and disclosures based on varying assumptions, which may be appropriate to use. In addition, the financial and operating environment may also have a significant effect, not only on the operation of the business, but on the results reported through the application of accounting measures used in preparing the financial statements and related disclosures, even if the nature of the accounting policies has not changed.
On an ongoing basis, the Company evaluates these estimates, utilizing historic experience, consultation with experts and other methods the Company considers reasonable. Actual results may differ substantially from the Company'sCompany’s estimates. Any effects on the Company'sCompany’s business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the information that gives rise to the revision becomes known.
The Company'sCompany’s significant accounting policies are summarized in Item 15 — Note 2, Summary of Significant Accounting Policies. The Company identifies its most critical accounting policies as those that are the most pervasive and important to the portrayal of the Company'sCompany’s financial position and results of operations, and that require the most difficult, subjective and/or complex judgments by management regarding estimates about matters that are inherently uncertain. The Company'sCompany’s critical accounting policies include accounting utilizing Hypothetical Liquidation at Book Value, or HLBV, acquisition accounting and acquisition accounting.determining the fair value of financial instruments.
| | | | | |
| Accounting Policy | Judgments/Uncertainties Affecting Application |
| |
| |
| |
| |
| |
| |
| Hypothetical Liquidation at Book Value (HLBV) | Estimates of taxable income (loss) and tax capital accounts |
| Estimated calculation of specified target investor returns |
| Application of liquidation provisions of operating agreements |
| |
| |
| |
| |
| Acquisition Accounting | Identification of assets acquired |
| Inputs for fair values of assets and liabilities acquired |
| Application of appropriate fair value methodologies |
| Financial Instruments | Use of unobservable market inputs such as future electricity prices, future interest rates and discount rates |
|
Hypothetical Liquidation at Book Value (HLBV)
Certain portions of the Company'sCompany’s redeemable noncontrolling interests in subsidiariesinterest 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 enteredwere established to finance the cost of wind facilities eligible for certain tax credits.credits and benefits. 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 investment in unconsolidated affiliatesnoncontrolling interest that reflects the substantive profit sharing arrangements is a balance sheet approach utilizing the HLBV method. Under the HLBV method, the amounts reported as redeemable noncontrolling interestsinterest and investment in unconsolidated affiliatesnoncontrolling 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'investors’ interests in the results of operations of the funding structures are determined as the difference in redeemable noncontrolling interestsinterest 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'funds’ investors. The calculations utilized to apply the HLBV method include estimated calculations of taxable income or losses for each reporting period as well as estimated calculations of tax capital accounts based on the relevant provisions of each agreement and the related tax guidance. In addition, these calculations often take into account the stipulated targeted investor return specified in the subsidiaries'subsidiaries’ operating agreement and agreed by the members of the arrangement. 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 statement of operationsincome using a systematic and rational method over the period during which the investor is expected to achieve its target return. In certain cases, the Company must apply judgment in determining the methodology for applying these concepts in the HLBV method and changes in certain factors may have a significant impact on the amounts that an investor would receive upon a hypothetical liquidation. The use of the HLBV method to allocate income (loss) to the noncontrolling interest holders may create volatility in the consolidated statements of operations.income.
Acquisition Accounting
The Company applies ASC 805, Business Combinations, when accounting for acquisitions, with identifiable assets acquired and liabilities assumed recorded at their estimated fair values at acquisition date. For many of the Company'sCompany’s acquisitions, the Company applies ASC 805-50, which provides that acquisitions of entities under common control are recorded at historical cost, except in the case where the ultimate parent has a different basis, such as when an acquiree did not elect to apply pushdown accounting. In those circumstances, the Company may also be required to record its acquired assets and liabilities at acquisition date fair value.
Significant judgment is required in determining the acquisition date fair value of the assets acquired and liabilities assumed, predominantly with respect to property, plant and equipment, power purchase agreements, asset retirement obligations and other contractual arrangements.arrangements for third-party acquisitions. Evaluations include numerous inputs including forecasted cash flows that incorporate the specific attributes of each asset including age, useful life, equipment condition and technology as well as current replacement costs for similar assets. Other key inputs that require judgment include discount rates, comparable market transactions, estimated useful lives and probability of future transactions. The Company evaluates all available information as well as all appropriate methodologies, when determining the fair value of assets acquired and liabilities assumed in a business combination. In addition, once the appropriate fair values are determined, the Company must determine the remaining useful life for property, plant and equipment and the amortization period and method of amortization for each finite-lived intangible asset.
Financial Instruments
The Company records its financial instruments, which primarily consist of derivative financial instruments, at fair value. The Company determines the fair value of its financial instruments using discounted cash flow models that require the use of assumptions concerning the amount of estimated future cash flows. The assumptions are determined using external, observable market inputs when available. When observable market inputs are not available, the Company must apply significant judgment to determine market participant assumptions such as future electricity prices, future interest rates and discount rates. As these inputs are based on estimates, fair values may not reflect the amounts actually realized from the related transaction.
Recent Accounting Developments
See Item 15 — Note 2, Summary of Significant Accounting Policies, for a discussion of recent accounting developments.
Item 7A — Quantitative and Qualitative Disclosures About Market Risk
The Company is exposed to several market risks in its normal business activities. Market risk is the potential loss that may result from market changes associated with the Company'sCompany’s power generation or with an existing or forecasted financial or commodity transaction. The types of market risks the Company is exposed to are commodity price risk, interest rate risk, liquidity risk, and credit risk.
Commodity Price Risk
Commodity price risks result from exposures to changes in spot prices, forward prices, volatilities, and correlations between various commodities, such as electricity natural gas and emissions credits. The Company manages the commodity price risk of its merchant generation operations by entering into derivative or non-derivative instruments to hedge the variability in future cash flows from forecasted power sales or purchases of fuel.sales. The portion of forecasted transactions hedged may vary based upon management'smanagement’s assessment of market, weather, operation and other factors. See Item 15 — Note 7, Accounting for Derivative Instruments and Hedging Activities, for more information.
Based on a sensitivity analysis using simplified assumptions, the impact of a $0.50 per MMBtu decrease in natural gas prices across the term of the derivative contracts would cause an increase of approximately $1 million to the net value of natural gas derivatives, and an increase of $0.50 MMBtu in natural gas prices across the term of the derivative contracts would cause an increase of approximately $3 million to the net value of natural gas derivatives as of December 31, 2021. The impact of a $0.50 per MWh increase or decrease in power prices across the term of the derivative contracts would cause a change of approximately $7$7 million to the net value of power derivatives as of December 31, 2021.2022.
Interest Rate Risk
The Company is exposed to fluctuations in interest rates through its issuance of variable rate debt. Exposures to interest rate fluctuations may be mitigated by entering into derivative instruments known as interest rate swaps, caps, collars and put or call options. These contracts reduce exposure to interest rate volatility and result in primarily fixed rate debt obligations when taking into account the combination of the variable rate debt and the interest rate derivative instrument. See Item 15 — Note 7, Accounting for Derivative Instruments and Hedging Activities, for more information.
Most of the Company'sCompany’s project subsidiaries enter into interest rate swaps, intended to hedge the risks associated with interest rates on non-recourse project level debt. See Item 15 — Note 10, Long-term Debt, for more information about interest rate swaps of the Company'sCompany’s project subsidiaries.
If all of the above swaps had been discontinued on December 31, 20212022, the Companycounterparties would have owed the counterparties $63Company $93 million. Based on the credit ratings of the counterparties, the Company believes its exposure to credit risk due to nonperformance by counterparties to its hedge contracts to be insignificant.
The Company has long-term debt instruments that subject it to the risk of loss associated with movements in market interest rates. As of December 31, 20212022, a 1% change in interest rates would result in an approximately $6$1 million change in interest expense on a rolling twelve-month basis.
As of December 31, 20212022, the fair value of the Company'sCompany’s debt was $7,998$6,288 million and the carrying value was $7,783$6,874 million. The Company estimates that a 1% decrease in market interest rates would have increased the fair value of its long-term debt by $540$358 million.
Liquidity Risk
Liquidity risk arises from the general funding needs of the Company'sCompany’s activities and in the management of the Company'sCompany’s assets and liabilities.
Counterparty Credit Risk
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, and (ii) the use of credit mitigation measures such as prepayment arrangements or volumetric limits. 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. See Item 15 — Note 6, Fair Value of Financial Instruments, for more information about concentration of credit risk.
Item 8 — Financial Statements and Supplementary Data
The financial statements and schedules are listed in Part IV, Item 15 of this Form 10-K.
Item 9 — Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
As previously reported in the Company'sCompany’s Current Report on Form 8-K filed on March 15, 2021, on March 9, 2021, the Audit Committee of the Board of Directors of the Company dismissed KPMG LLP as the Company'sCompany’s independent registered public accounting firm and appointed Ernst & Young LLP, (PCAOB ID:42), an independent registered public accounting firm, to audit the consolidated financial statements of the Company and its subsidiaries for the fiscal year ending December 31, 2021. For more information, please refer to the Company'sCompany’s Current Report on Form 8-K filed on March 15, 2021.
Item 9A — Controls and Procedures
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures and Internal Control Over Financial Reporting
Under the supervision and with the participation of the Company'sCompany’s management, including its principal executive officer, principal financial officer and principal accounting officer, the Company conducted an evaluation of the effectiveness of the design and operation of its disclosure controls and procedures, as such term is defined in Rules 13a-15(e) or 15d-15(e) of the Exchange Act. Based on this evaluation, the Company'sCompany’s principal executive officer, principal financial officer and principal accounting officer concluded that the disclosure controls and procedures were effective as of the end of the period covered by this Annual Report on Form 10-K.
Changes in Internal Control over Financial Reporting
There were no changes in the Company'sCompany’s internal control over financial reporting (as such term is defined in Rule 13a-15(f) under the Exchange Act) during the quarter ended December 31, 2021,2022, that materially affected, or are reasonably likely to materially affect, the Company'sCompany’s internal control over financial reporting.
Inherent Limitations over Internal Controls
The Company'sCompany’s internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of consolidated financial statements for external purposes in accordance with GAAP. The Company'sCompany’s internal control over financial reporting includes those policies and procedures that:
1. Pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the Company'sCompany’s assets;
2. Provide reasonable assurance that transactions are recorded as necessary to permit preparation of consolidated financial statements in accordance with GAAP, and that the Company'sCompany’s receipts and expenditures are being made only in accordance with authorizations of its management and directors; and
3. Provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company'sCompany’s assets that could have a material effect on the consolidated financial statements.
Internal control over financial reporting cannot provide absolute assurance of achieving financial reporting objectives because of its inherent limitations, including the possibility of human error and circumvention by collusion or overriding of controls. Accordingly, even an effective internal control system may not prevent or detect material misstatements on a timely basis. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions or that the degree of compliance with the policies or procedures may deteriorate.
Management'sManagement’s Report on Internal Control over Financial Reporting
The Company'sCompany’s management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Under the supervision and with the participation of the Company'sCompany’s management, including its principal executive officer, principal financial officer and principal accounting officer, the Company conducted an evaluation of the effectiveness of its internal control over financial reporting based on the framework in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the Company'sCompany’s evaluation under the framework in Internal Control — Integrated Framework (2013), the Company'sCompany’s management concluded that its internal control over financial reporting was effective as of December 31, 2021.2022.
Item 9B — Other Information
None.
PART III
PART III
Item 10 -— Information about Directors, Executive Officers and Corporate Governance
The Company is a limited liability company that is managed by Clearway, Inc., as its sole managing member. As a limited liability company managed by Clearway, Inc., the Company does not have a board of directors. References herein to the Company'sCompany’s board of directors are references to the board of directors (the “Board”) of Clearway, Inc. Pursuant to the Fourth Amended and Restated Limited Liability Company Agreement of the Company, Clearway, Inc. has appointed officers of the Company and designated certain of such officers as “Executive Officers.” These executive officers are the same as the executive officers of Clearway, Inc.
The following table shows information for the Company'sCompany’s executive officers. Executive officers serve until their successors are duly appointed or elected.
| | | | | | | | |
| Name | Age | Title |
| Christopher S. Sotos | 5051 | President and Chief Executive Officer |
Chad PlotkinSarah Rubenstein | 4645 | Senior Vice President, and Chief FinancialAccounting Officer |
| Kevin P. Malcarney | 5556 | Senior Vice President, General Counsel and Corporate Secretary |
Christopher S. Sotos has served as President and Chief Executive Officer since May 2016, and as a member of the Board of Clearway, Inc. since May 2013. Mr. Sotos had also served in various positions at NRG, including most recently as Executive Vice President-Strategy and Mergers and Acquisitions from February 2016 through May 2016 and Senior Vice President-Strategy and Mergers and Acquisitions from November 2012 through February 2016. In this role, he led NRG’s corporate strategy, mergers and acquisitions, strategic alliances and other special projects for NRG. Previously, he served as NRG’s Senior Vice President and Treasurer from March 2008 to September 2012, where he was responsible for all treasury functions, including raising capital, valuation, debt administration and cash management. Mr. Sotos also previously served as a director of FuelCell Energy, Inc. from September 2014 to April 2019. As President and Chief Executive Officer of the Company, Mr. Sotos provides the Board of Clearway, Inc. with management’s perspective regarding the Company’s day to day operations and overall strategic plan. Mr. Sotos also brings strong financial and accounting skills to the Board of Clearway, Inc.
Chad PlotkinSarah Rubenstein has served as the Company’s Chief Financial Officer since November 2016 and was promoted from Senior Vice President to Executive Vice President in January 2022. From January 2016 until his appointment as Senior Vice President and Chief FinancialAccounting Officer in November 2016, Mr. Plotkinof the Company since January 2022 and previously served as Senior Vice President, Finance and Strategy. Prior to this, he served in varying capacities at NRG, including as Vice President and Controller from November 2020 through December 2021. Ms. Rubenstein previously served as Assistant Controller of Investor Relations of both the Company since August 2018, where she was responsible for managing corporate accounting and financial reporting activities, and immediately prior to that, as Director of Accounting Research and Financial Reporting at NRG Energy, Inc. from September 2015 to January 2016 and from JanuaryAugust 2012 to February 2015 and Vice Presidentthrough August 2018. Ms. Rubenstein’s prior roles include Director of Finance at EPV Solar, Inc. and Senior Director of NRG from February 2015 to September 2015. From October 2007 to January 2012, Mr. Plotkin served in various capacities in the Strategy and Mergers and Acquisitions group of NRG, includingFinancial Reporting at Warner Music Group. Ms. Rubenstein began her career as Vice President, beginning in December 2010.an auditor with PricewaterhouseCoopers.
Kevin P. Malcarney has served as the Company’s General Counsel and Corporate Secretary since May 11, 2018, and was promoted from Senior Vice President to Executive Vice President in January 2022. Mr. Malcarney served as Interim General Counsel of the Company from March 16, 2018 to May 11, 2018. Mr. Malcarney was previously Vice President and Deputy General Counsel and served in various other roles at NRG since September 2008. Prior to NRG, Mr. Malcarney worked at two major law firms in Princeton, New Jersey and Philadelphia, Pennsylvania, and handled mergers and acquisitions, project financing and general corporate matters.
Code of Ethics
The Company has not adopted a separate code of ethics because all of the officers of the Company are subject to the Code of Conduct adopted by the Board of Clearway, Inc. The Code of Conduct of Clearway, Inc. applies to all of its directors and employees, including its and the Company'sCompany’s officers (e.g., the Company'sCompany’s CEO, CFO, and Principal Accounting Officer). Clearway, Inc.’s Code of Conduct is available on its website, www.clearwayenergy.com.
Item 11 — Executive Compensation
Compensation Committee Report
The Company'sCompany’s named executive officers are also named executive officers of Clearway, Inc., and the compensation of the named executive officers disclosed herein reflects total compensation for services with respect to Clearway, Inc. and all of its subsidiaries, including the Company. The Compensation Committee of the Board of Clearway, Inc. (the “Compensation Committee”) has reviewed and discussed the Compensation Discussion and Analysis included in this Annual Report on Form 10-K required by Item 402(b) of Regulation S-K with management and, based upon such review and discussion, the Compensation Committee has recommended to the Board that the Compensation Discussion and Analysis be included in this Annual Report on Form 10-K.
| | | |
| Compensation Committee: |
| Ferrell P. McClean,E. Stanley O’Neal, Chair |
| Jonathan Bram |
| Brian R. Ford |
| Daniel B. MoreJennifer Lowry |
| E. Stanley O'NealDaniel B. More |
Compensation Discussion and Analysis
Executive Summary
Executive Compensation Program
Clearway, Inc. is a publicly-traded energy infrastructure investor and owner of modern, sustainable and long-term contracted assets across North America. GIP, through its portfolio company, CEG, holds all of Clearway, Inc.’s Class B common stock and Class D common stock, and thus has the majority voting interest in the Company. This Compensation Discussion and Analysis (this “CD&A”) describes the philosophy, elements, implementation and results of the Clearway, Inc.'s 2021 executive compensation program as it applies to the executive team. As discussed above, Clearway, Inc.’s named executive officers are also named executive officers of Clearway Energy LLC, and the compensation of the named executive officers (“NEOs”) discussed below reflects total compensation for services with respect to Clearway, Inc. and all of its subsidiaries, including Clearway Energy LLC. In this CD&A, the term “Company,” as well as the terms “our,” “we,” “us” or like terms, are used to refer to Clearway, Inc. and its consolidated subsidiaries, including Clearway Energy LLC and its consolidated subsidiaries.
The Compensation Committee’s objectives are to design a simple yet competitive program, which is aligned with the interests of our stockholders. This program is designed to align short-term and long-term compensation with the Company’s annual performance and three-year total stockholder return (“TSR”), respectively. Our annual incentive program (“AIP”) is primarily based on objective criteria that support the achievement of our short-term objectives, which we believe create long-term stockholder value. Our long-term incentives are comprised of 67% Relative Performance Stock Units (“RPSUs”), which vest based on relative TSR measured over three years and 33% Restricted Stock Units (“RSUs”), which vest based on continued service over three years. The program incorporates many best practices in compensation design, while being tailored to our business needs and compensation objectives.
In 2021, the Compensation Committee reviewed and did not modify its philosophy related to the compensation program. Thus, NEO compensation continued to be delivered through a mix of (i) base salary, (ii) an annual incentive bonus opportunity under the AIP and (iii) long-term incentive compensation under our Amended and Restated 2013 Equity Incentive Plan (“LTIP”) in the form of RPSUs and RSUs.
At our 2021 Annual Meeting of Stockholders, we received approximately 99% support for our say on pay proposal. We believe these results demonstrate our stockholders support our pay practices and that our compensation program is aligned with their interests.
Key Governance Features of Our Executive Compensation Program
Our compensation program and practices incorporate several key governance features as highlighted in the table below.
| | | | | |
What We Do: | What We Don’t Do: |
•Pay for performance by delivering a substantial majority of our President and CEO’s compensation through equity
| •No excise tax gross‑ups on change‑in‑control payments and no tax gross‑ups on perquisites or benefits
|
•The large majority of our equity compensation for Senior Vice Presidents and above is performance‑based
| •No pledging or hedging of the Company’s stock by NEOs or directors
|
•Target our peer group median for total direct compensation
| •No employment agreements for executive officers with the exception of our President and CEO
|
•Require a double trigger for the acceleration of equity vesting in connection with a change‑in‑control
| •No guaranteed bonus payments for our NEOs
|
•Prevent undue risk taking in our compensation practices and engage in robust risk monitoring
| •No supplemental executive retirement plans
|
•Include clawback policies in our compensation plans
| •No re‑pricing of underwater stock options and no stock option grants with an exercise price below 100% of fair market value
|
•Maintain robust stock ownership guidelines for our NEOs
| |
•Provide market‑level retirement benefits and limited perquisites
| |
•Engage an independent compensation consultant to provide advice to the Compensation Committee with respect to our compensation program
| |
•Conduct an annual say on pay vote
| |
Business Strategy and Company Performance
The Company’s primary business strategy is to focus on the acquisition and ownership of assets with predictable, long-term cash flows that allow the Company to increase the cash dividends paid to holders of the Company’s Class A and Class C common stock over time without compromising the ongoing stability of the business. The Company’s plan for executing this strategy includes the following key components: focusing on contracted renewable energy and conventional generation and thermal infrastructure assets; growing our business through acquisitions of contracted operating assets primarily in North America; and maintaining sound financial practices to grow our dividend.
The execution of the Company’s business strategy produced the following results in 2021:
•Raised approximately $1.61 billion in new capital formation for growth investments and liability management, which included corporate level debt and equity financings, the optimization of non-recourse project level debt, and the recycling of non-strategic assets
•Invested or committed approximately $165 million in new growth investments with CEG
•Closed the acquisition of an additional 35% equity interest in the Agua Caliente solar project from NRG Energy, Inc., for $202 million
•Entered into an agreement to sell its Thermal Business to KKR, which sale is expected to close in the first half of 2022
•Closed the acquisition of Rattlesnake, Mesquite Sky and Black Rock wind projects from CEG
•Completed the repowering of the Pinnacle Wind Farm
•Signed and closed acquisitions of an additional 50% equity interest in Utah Solar from Dominion Energy for $335 million and a 100% equity interest in Mt. Storm Wind from Castleton Commodities International for $96 million
•Entered into resource adequacy contracts at Marsh Landing and Walnut Creek to extend the contracted term of both assets
Such results were taken into account by the Compensation Committee in making determinations with respect to the compensation for our NEOs under the 2021 compensation program.
Executive Compensation Program
2021Clearway, Inc. is a publicly-traded energy infrastructure investor 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, CEG, and, together, GIP and TotalEnergies hold all of Clearway, Inc.’s Class B common stock and Class D common stock and thus collectively have the majority voting interest in the Company. This Compensation Discussion and Analysis (this “CD&A”) describes the philosophy, elements, implementation and results of Clearway, Inc.’s 2022 executive compensation program as it applies to the executive team. As discussed above, Clearway, Inc.’s named executive officers are also named executive officers of Clearway Energy LLC, and the compensation of the named executive officers (“NEOs”) discussed below reflects total compensation for services with respect to Clearway, Inc. and all of its subsidiaries, including Clearway Energy LLC. In this CD&A, the term “Company,” as well as the terms “our,” “we,” “us” or like terms, are used to refer to Clearway, Inc. and its consolidated subsidiaries, including Clearway Energy LLC and its consolidated subsidiaries.
The Compensation Committee’s objectives are to design a simple yet competitive program, which is aligned with the interests of our stockholders. This program is designed to align short-term and long-term compensation with the Company’s annual performance and three-year total stockholder return (“TSR”), respectively. Our annual incentive program (“AIP”) is primarily based on objective criteria that support the achievement of our short-term objectives, which we believe create long-term stockholder value. Our long-term incentives are comprised of 67% Relative Performance Stock Units (“RPSUs”), which vest based on relative TSR measured over three years and 33% Restricted Stock Units (“RSUs”), which vest based on continued service over three years. The program incorporates many best practices in compensation design, while being tailored to our business needs and compensation objectives.
In 2022, the Compensation Committee reviewed and did not modify its philosophy related to the compensation program. Thus, NEO compensation continued to be delivered through a mix of (i) base salary, (ii) an annual incentive bonus opportunity under the AIP and (iii) long-term incentive compensation under our Amended and Restated 2013 Equity Incentive Plan (“LTIP”) in the form of RPSUs and RSUs.
At our 2022 Annual Meeting of Stockholders, we received approximately 99% support for our say on pay proposal. We believe these results demonstrate our stockholders support our pay practices and that our compensation program is aligned with their interests.
Key Governance Features of Our Executive Compensation Program
Our compensation program and practices incorporate several key governance features as highlighted in the table below.
| | | | | |
| What We Do: | What We Don’t Do: |
•Pay for performance by delivering a substantial majority of our President and CEO’s compensation through equity | •No excise tax gross‑ups on change‑in‑control payments and no tax gross‑ups on perquisites or benefits |
•The large majority of our equity compensation for Senior Vice Presidents and above is performance‑based | •No pledging or hedging of the Company’s stock by NEOs or directors |
•Target our peer group median for total direct compensation | •No employment agreements for executive officers with the exception of our President and CEO |
•Require a double trigger for the acceleration of equity vesting in connection with a change‑in‑control | •No guaranteed bonus payments for our NEOs |
•Prevent undue risk taking in our compensation practices and engage in robust risk monitoring | •No supplemental executive retirement plans |
•Include clawback policies in our compensation plans | •No re‑pricing of underwater stock options and no stock option grants with an exercise price below 100% of fair market value |
•Maintain robust stock ownership guidelines for our NEOs | |
•Provide market‑level retirement benefits and limited perquisites | |
•Engage an independent compensation consultant to provide advice to the Compensation Committee with respect to our compensation program | |
•Conduct an annual say on pay vote | |
Business Strategy and Company Performance
The Company’s primary business strategy is to focus on the acquisition and ownership of assets with predictable, long-term cash flows that allow the Company to increase the cash dividends paid to holders of the Company’s Class A and Class C common stock over time without compromising the ongoing stability of the business. The Company’s plan for executing this strategy includes the following key components: focusing on contracted renewable energy and conventional generation; growing our business through acquisitions of contracted operating assets primarily in North America; and maintaining sound financial practices to grow our dividend.
The execution of the Company’s business strategy produced the following results in 2022:
•Closed the sale of its Thermal Business to KKR for $1.9 billion
•Invested approximately $255 million in the acquisition of the Capistrano Wind Portfolio, which consists of five wind projects representing 413 MW of capacity
•Invested or committed approximately $309 million in new growth investments with CEG, including the commitment to acquire Victory Pass and Arica solar and energy storage projects and funding the Company’s interest in the Mililani and Waiawa solar projects, as well as incremental fundings for the Black Rock, Mesquite Sky and Pinnacle wind projects
•Entered into resource adequacy contracts for El Segundo and Marsh Landing, resulting in both assets having capacity sales fully contracted on a weighted average basis through the majority of 2026
Such results were taken into account by the Compensation Committee in making determinations with respect to the compensation for our NEOs under the 2022 compensation program.
Executive Compensation Program
2022 Named Executive Officers
This CD&A describes the material components of our compensation program for our NEOs in 2021.2022. For the year ending December 31, 2021,2022, our NEOs included the following individuals:
| | | | | | | | |
| NEO | | 20212022 Title |
| Christopher S. Sotos | | President and Chief Executive Officer |
Chad PlotkinSarah Rubenstein | | Senior Vice President and Chief FinancialAccounting Officer(1) |
| Kevin P. Malcarney | | SeniorExecutive Vice President, General Counsel and Corporate Secretary(2)
|
| Chad Plotkin | | Executive Vice President and Chief Financial Officer(3) |
(1) Ms. Rubenstein was promoted to Senior Vice President and Chief Accounting Officer in January 2022 and appointed as the principal financial officer for the Company in August 2022.
(2) Mr. Malcarney was promoted to Executive Vice President, General Counsel and Corporate Secretary in January 2022.
(3) Mr. Plotkin was promoted to Executive Vice President and Chief Financial Officer in January 2022. Mr. Plotkin voluntarily resigned from his employment with the Company in August 2022.
Goals and Objectives of the Program
The Compensation Committee is responsible for the development and implementation of the Company’s executive compensation program, subject to Board approval for equity awards to certain officers, and references to Compensation Committee actions described below should be read in a manner that contemplates the requisite Board approval, as applicable, is in effect (see “Board Committees—Compensation Committee” above). The intent of the program is to reward the achievement of the Company’s annual goals and objectives while supporting the Company’s long-term business strategy. The Compensation Committee is committed to aligning executives’ compensation with performance. Our Compensation Committee has designed an executive compensation program that:
•closely aligns our executive compensation with stockholder value creation, avoiding plans that encourage executives to take excessive risk, while driving long-term value to stockholders;
•supports the Company’s long-term business strategy, while rewarding our executive team for their individual accomplishments with tailored individual executive compensation metrics and incentives; and
•provides a competitive compensation opportunity while aligning with market standards for compensation.
The Compensation Committee’s objectives are achieved through the use of both short-term and long-term incentives. The Company currently targets total direct compensation at the median of our Compensation Peer Group (defined below), as described below under “Elements of Compensation.”
The Compensation Process
Compensation Consultant
Pursuant to its charter, the Compensation Committee is authorized to engage, at the expense of the Company, a compensation consultant to provide independent advice, support and expertise to assist the Compensation Committee in overseeing and reviewing our overall executive compensation strategy, structure, policies and programs, and to assess whether our compensation structure establishes appropriate incentives for management and other key employees. Pay Governance has been the Compensation Committee’s independent compensation consultant since August 2020, and Pay Governance has continued to serve in that capacity to the present date. Pay Governance worked with the Compensation Committee to formulate the design of the executive and director compensation programs for 2021.2022. As part of its work with the Compensation Committee, Pay Governance provided reports to the Compensation Committee containing research, market data, survey information and information regarding trends and developments in executive and director compensation.compensation, and Pay Governance reported directly to the Compensation Committee. Neither Pay Governance, nor any of their affiliates provided any other services for us or any of our affiliates in 2021.2022. In accordance with SEC rules and requirements, the Company has affirmatively determined that no conflicts of interest exist between the Company and Pay Governance (or any individuals working on the Company’s account on behalf of Pay Governance).
Compensation Peer Group Analysis
The Compensation Committee, with support from its independent compensation consultant, identifies the most appropriate comparator group within relevant industries for purposes of benchmarking compensation. The Compensation Committee aims to compare our compensation program to a consistent peer group year-to‑year but given the dynamic nature of our industry and the companies that constitute it, the Compensation Committee annually examines the peer group for appropriateness in terms of size, complexity, and industry. As a result of such annual review, the Compensation Committee identified a new peer group for compensation benchmarking purposes in 20212022 (the “Compensation Peer Group”).
For these purposes, the Compensation Peer Group, comprised of similarly sized publicly-owned energy and utility companies, is identified below:
| | | | | | | | | | | | | | | | | | | | |
| Company | | Ticker | | Company | | Ticker |
| Algonquin Power & Utilities Corp. | | NYSE: AQN | | MGE Energy, Inc. | | NASDAQ: MGEE |
| Alliant Energy Corporation | | NASDAQ: LNT | | Northland Power Inc. | | TSX: NPI |
| Atmos Energy Corporation | | NYSE: ATO | | NorthWestern Corporation | | NYSE: NWE |
| Avista Corporation | | NYSE: AVA | | Ormat Technologies, Inc. | | NYSE: ORA |
| Black Hills Corporation | | NYSE: BKH | | NorthWestern CorporationPortland General Electric Company | | NYSE: NWEPOR |
Covanta Holding Corporation(1) | | NYSE: CVA | | Ormat Technologies,South Jersey Industries, Inc. | | NYSE: ORASJI |
| Equitrans Midstream Corporation | | NYSE: ETRN | | TransAltaCorporation. | | NYSE:TAC |
| Genesis Energy, L.P. | | NYSE: GEL | | South Jersey Industries, Inc. | | NYSE: SJI |
| Innergex Renewable Energy Inc. | | TSX: INE | | Suburban Propane Partners, L.P. | | NYSE:SPH |
MGE Energy, Inc. | | NASDAQ: MGEE | | TransAltaCorporation. | | NYSE:TAC |
(1) Covanta Holding Corporation was acquired by the EQT Infrastructure V Fund in November 2021 and was delisted, but was included by Pay Governance as part of its 20212022 compensation benchmarking analysis. Accordingly,analysis, and for that reason, Covanta Holding Corporation is included in the Compensation Peer Group for 20212022 but will not be part of the Compensation Peer Group for 20222023 or going forward.
For the purposes of determining appropriate NEO pay levels for 2021,2022, the Compensation Committee reviewed NEO compensation from peers, where available and appropriate (e.g., based on an NEO’s position and duties). To supplement this analysis, the Compensation Committee reviewed relevant third-party survey data and considered the recommendations of the CEO on NEO and employee compensation matters not involving the CEO. The Compensation Committee may accept or adjust such CEO recommendations at its discretion. The NEOs did not participate in the Compensation Committee discussions regarding their own compensation.
Elements of Compensation
Our compensation program for our NEOs consists of fixed compensation (base salary), performance-based compensation (AIP bonus and RPSUs) and time-based compensation (RSUs). We use the median percentile of our Compensation Peer Group as a guidepost in establishing the targeted levels of total direct compensation (cash and equity) for our NEOs. We expect that, over time, targeted total direct compensation for our NEOs will continue to approximate the median of our Compensation Peer Group. Realized pay in a given year depends on the achievement of defined performance-based compensation metrics. While a portion of our NEOs’ compensation is fixed, a significant percentage is at-risk and payable and/or realizable only if certain performance objectives are met.
Base Salary
Base salary compensates NEOs for their level of experience and position responsibilities and for the continued expectation of superior performance. Recommendations on increases to base salary take into account, among other factors, the NEO’s individual performance, the general contributions of the NEO to overall corporate performance, the level of responsibility of the NEO with respect to his or her specific position, and the NEO'sNEO’s current base salary level compared to the market median. Mr. Sotos received a base salary increase in 2022 based on his performance and peer group benchmarking. Messrs. Sotos,Malcarney and Plotkin and MalcarneyMs. Rubenstein received base salary increases in 20212022 based on their promotions, performance and peer group benchmarking. The base salary for each NEO for fiscal year 20212022 is set forth below:
| | Named Executive Officer | Named Executive Officer | | 2021 Annualized Base Salary ($)(1) | | Percentage Increase Over 2020 (%)(2) | Named Executive Officer | | 2022 Annualized Base Salary ($)(1) | | Percentage Increase Over 2021 (%)(2) |
| Christopher S. Sotos | Christopher S. Sotos | | 629,300 | | | 3% | Christopher S. Sotos | | 665,201 | | | 6% |
| Chad Plotkin | | 391,400 | | | 3% | |
Sarah Rubenstein(3) | | Sarah Rubenstein(3) | | 325,000 | | | 15% |
Kevin P. Malcarney | Kevin P. Malcarney | | 320,000 | | | 4% | Kevin P. Malcarney | | 400,000 | | | 25% |
Chad Plotkin(5) | | Chad Plotkin(5) | | 460,000 | | | 18% |
(1) Actual 20212022 base salary earnings are presented in the Summary Compensation Table.
(2) As compared to the December 31, 20202021 annualized base salary.
(3) Ms. Rubenstein was promoted to Senior Vice President and Chief Accounting Officer in January 2022 and appointed as the principal financial officer for the Company in August 2022.
(4) Mr. Malcarney was promoted to Executive Vice President, General Counsel and Corporate Secretary in January 2022.
(5) Mr. Plotkin was promoted to Executive Vice President and Chief Financial Officer in January 2022. Mr. Plotkin voluntarily resigned from his employment with the Company in August 2022. Mr. Plotkin earned $278,219 prior to his departure.
Annual Incentive Compensation
Overview
Annual incentive compensation awards (AIP bonuses) are made under our AIP. AIP bonuses represent short-term compensation designed to compensate NEOs for meeting annual Company goals and for their individual performance over the course of the year. The Compensation Committee establishes these annual Company goals after reviewing the Company’s business strategy and other matters. As further discussed below, the annual goals for 20212022 relate to the following three areas:to: (a) CAFD and (b) key performance milestones, and (c) achievement of the Thermal Plan (as described below).milestones. In addition, the overall bonus payout is negatively adjusted for any OSHA recordable injuries that occur during the year, and each NEO’s individual performance may (negatively or positively) affect the bonus amount that he or she ultimately receives under our AIP. However, notwithstanding individual performance or the extent to which the Company goals are achieved, the Compensation Committee retains sole discretion under the AIP to reduce the amount of or eliminate any AIP bonuses that are otherwise payable under the AIP.
AIP bonus opportunities are expressed in terms of threshold, target and maximum bonus opportunities. Different percentages of each NEO’s annual base salary relate to these threshold, target and maximum AIP bonus opportunities. However, in the event threshold performance for 20212022 was not achieved with respect to one of the AIP performance metrics, no AIP bonuses would have been payable for that component for 2021.2022.
The AIP provides NEOs (other than Mr. Sotos whose severance is governed by his amended and restated employment agreement) eligibility for a pro-rated target bonus payment for the year of a qualifying severance termination, based on the portion of the performance period that the NEO was employed.
2022 AIP Bonus Performance Criteria
The 2022 AIP bonus performance criteria applicable to all NEOs are based upon the threetwo Company goals described above and adjusted, as discussed, based on OSHA recordable injuries and individual performance.performance, as applicable. As a result of the announcement of Company’s sale of its Thermal Business to KKR in the fourth quarter of 2021, and the closing of such sale in the second quarter of 2022, the 2021 AIP metrics that related to the Thermal Plan were removed for 2022. The table below sets forth the 20212022 AIP performance criteria and weightings applicable to all NEOs, assuming the achievement of each goal at target.
| | | | | |
| Goal | Weight |
CAFD(1) | 35%40% |
| Key Performance Milestones | 55%60% |
| |
Achievement of the Thermal Plan | 10% |
| Overall Funding | 100% |
| OSHA Recordables (per recordable injury) | -5% |
| Individual Performance | +/- 20% |
(1) A non-GAAP measure, CAFD is defined as adjusted earnings before interest, taxes, depreciation and amortization (Adjusted EBITDA) plus cash distributions/return of investment from unconsolidated affiliates, and subsequent release post-bankruptcy, cash receipts from notes receivable, cash distributions from noncontrolling interests, adjustments to reflect sales-type lease cash payments, less cash distributions to noncontrolling interests, maintenance capital expenditures, pro-rata Adjusted EBITDA from unconsolidated affiliates, cash interest paid, income taxes paid, principal amortization of indebtedness, changes in prepaid and accrued capacity payments, and adjusted for development expenses.
•CAFD. The Compensation Committee set the 20212022 threshold, target and maximum CAFD performance metric at $272$292 million, $340$365 million and $408$438 million, respectively. For 2021,2022, the CAFD goals and the achieved level are set forth in the chart below. The Company achieved CAFD of approximately $336$326 million, surpassing the CAFD threshold but less than the CAFD target.
| | | | | | | | | | | |
CAFD Threshold | CAFD Target | CAFD Maximum | CAFD Actual |
$272292 million | $340365 million | $408438 million | $336326 million |
•Key Performance Milestones. “Key performance milestones” performance metrics are established as a defined annual incentive category. The Compensation Committee establishes threshold, target and maximum levels of performance for this category based on the number of milestones achieved. For 2021,2022, a total of eightseven milestones were established relating to the Company’s credit rating, ESG matters, adherence to budget, CAFD per share goals, ratio of administrative costs to CAFD corporate process improvement, Thermaland natural gas strategic plan and OSHA recordable incident rate. Additional CAFD and safety-related goals also applied with respect to the Company’s Thermal Business.execution. For 2021,2022, threshold performance required the achievement of threetwo out of the eightseven milestones, target performance required the achievement of four out of the eightseven milestones, and maximum performance required the achievement of all eightseven milestones. Ultimately, above target performance was attained with the achievement of sevenfive out of the eightseven milestones in 2021.
•Achievement of the Thermal Plan. Achievement of “Thermal Plan” performance metrics was added as an annual incentive category beginning in 2019 based on the view that all elements of the Company’s business should be reflected in the AIP bonus opportunity. The Compensation Committee established threshold, target and maximum levels for this category for each of the “Thermal Plan” performance metrics. For 2021, the Thermal Plan performance metrics relate to the Thermal Business’s CAFD, growth and five key Thermal Plan goals. Similar to the key performance milestones described above, threshold, target and maximum levels of performance were established for the key Thermal Plan goals based on the number of goals achieved. These goals related to safety, succession planning, and formalizing processes related to business operations, in each case, with respect to the Thermal Business (threshold, target and maximum performance required the achievement of one, three and five goals, respectively, out of a total of five). Ultimately, above-target performance was attained (expressed as 126% of target) with respect to the Thermal Plan in 2021. As noted above, the Company is expected to complete the Thermal Disposition in the first half of 2022. As a result, it is anticipated that the AIP metrics that relate to the Thermal Plan will be modified in 2022.
•Individual Performance. As indicated above, an NEO’s individual performance may (negatively or positively) affect his or her AIP bonus by up to 20%, although no AIP bonus payments can exceed 200% of the target award. Such individual performance is determined on a subjective basis based on the Compensation Committee’s assessment of the NEO’s contributions in supporting adherence to budget, support towards the achievement of key milestones, and other contributions towards the successful execution of the Company’s business strategy. In light of the Company’s above-target achievement of AIP bonus performance criteria in 2021, theThe Compensation Committee recommended to the full Board that the CEO’s AIP bonus be paid based on the overall 20212022 AIP achievement without additional modification. Similarly, the CEO recommended to the Compensation Committee that the AIP bonus for the other NEOs be paid based on the overall 20212022 AIP achievement without additional modification. The full board approved the above recommendation of the Compensation Committee for the CEO and the Compensation Committee approved the above recommendation of the CEO for the other NEOs.
2022 Annual Incentive Bonus Opportunity
The threshold, target and maximum AIP bonus opportunities for NEOs for 2021,2022, expressed as a percentage of base salary, were:
| | Named Executive Officer | Named Executive Officer | | Threshold (%)(1) | Target (%)(1) | Maximum (%)(1) | Target Amount ($) | Named Executive Officer | | Threshold (%)(1) | Target (%)(1) | Maximum (%)(1) | Target Amount ($) |
| Christopher S. Sotos | Christopher S. Sotos | | 50 | 100 | 200 | 629,330 | Christopher S. Sotos | | 50 | 100 | 200 | 665,201 |
| Chad Plotkin | | 30 | 60 | 120 | 234,840 | |
Sarah Rubenstein(2) | | Sarah Rubenstein(2) | | 25 | 50 | 100 | 162,500 |
Kevin Malcarney(2)(3) | Kevin Malcarney(2)(3) | | 30 | 60 | 120 | 192,000 | Kevin Malcarney(2)(3) | | 32.5 | 65 | 130 | 260,000 |
Chad Plotkin(4) | | Chad Plotkin(4) | | 35 | 70 | 140 | 322,000 |
(1) This assumes that the CAFD performance metric and all other quantitative and qualitative goals, including the key milestones, are achieved at threshold, target and maximum levels, as applicable.
(2) Ms. Rubenstein was promoted to Senior Vice President and Chief Accounting Officer in January 2022 and appointed as the principal financial officer for the Company in August 2022.
(3) Mr. Malcarney'sMalcarney’s threshold, target and maximum AIP award were increased in 20212022 in connection with his promotion, to recognize his performance, and better align his total direct compensation with the market median.
2021(4) Mr. Plotkin’s threshold, target and maximum AIP award were increased in 2022 in connection with his promotion, to recognize his performance, and better align his total direct compensation with the market median. Mr. Plotkin voluntarily resigned from his employment with the Company in August 2022. Accordingly, no AIP bonus was paid to Mr. Plotkin for 2022.
2022 Annual Incentive Bonuses
As noted above, with respect to AIP bonuses for 2021,2022, the CAFD target was $340$365 million and the key performance milestone target was achievement of fourfive out of eightseven key performance milestones and target achievement of the “Thermal Plan” metrics was based on the achievement of various sub-categories, including the achievement of three out of five key Thermal Plan goals.milestones.
For 2021,2022, CAFD achievement was between threshold and target at approximately $336$326 million, and sevenfive out of eightseven key performance milestones were achieved. In addition, overall achievement for the Thermal Plan for 2021 was above target at 126%.achieved, and there were no OSHA recordable injuries. Due to the achievement specified above, 20212022 AIP bonuses were paid at levels above target. If performance falls between threshold and target or target and maximum, the bonus opportunity will be determined on an interpolated basis. As a result, the CAFD metric and the key performance milestone and Thermal Plan metrics were respectively weighted at 97%, 175%,73% and 126%133% of target.
The annual incentive bonuses paid to NEOs for 20212022 were:
| | Named Executive Officer | Named Executive Officer | | Target Percentage of Annual Base Salary (%) | | Percent of Annual Base Salary Achieved (%) | | Annual Incentive Payment ($) | Named Executive Officer | | Percentage of Annual Base Salary Achieved (%) | | Percent of Target Achieved (%) | | Annual Incentive Payment ($) |
| Christopher S. Sotos | Christopher S. Sotos | | 100 | | 143 | | 899,312 | | Christopher S. Sotos | | 109 | | 109 | | 725,069 | |
| Chad Plotkin | | 60 | | 86 | | 335,586 | | |
Sarah Rubenstein(1) | | Sarah Rubenstein(1) | | 55 | | 109 | | 177,125 | |
Kevin P. Malcarney | Kevin P. Malcarney | | 60 | | 86 | | 274,368 | | Kevin P. Malcarney | | 71 | | 109 | | 283,400 | |
Chad Plotkin(3) | | Chad Plotkin(3) | | N/A | | N/A | | N/A |
(1) Ms. Rubenstein was promoted to Senior Vice President and Chief Accounting Officer in January 2022 and appointed as the principal financial officer for the Company in August 2022. Ms. Rubenstein’s AIP target increased from 40% to 50% in connection with her promotion.
(2) Mr. Malcarney was promoted to Executive Vice President, General Counsel and Corporate Secretary in January 2022. Mr. Malcarney’s AIP target increased from 60% to 65% in connection with his promotion.
(3) Mr. Plotkin was promoted to Executive Vice President and Chief Financial Officer in January 2022. Mr. Plotkin’s AIP target increase from 60% to 70% in connection with his promotion. Mr. Plotkin voluntarily resigned from his employment with the Company in August 2022. Accordingly, no AIP bonus was paid to Mr. Plotkin for 2022.
Long‑Term Incentive Compensation
We believe that equity awards directly align our NEOs’ interests with those of our stockholders. In 2021,2022, the Compensation Committee granted our NEOs a combination of performance-based equity awards directly linked to long-term stockholder value creation and time-based equity awards which also represent a critical component of our long-term incentive compensation due to the retention aspects of the awards. To enhance our compensation program’s focus on Company performance, the majority of these long-term incentive awards (67%) were performance-based (i.e., granted as RPSUs). The remainder of our long-term incentive awards (33%) were time-based (i.e., granted as RSUs which vest over three years). We believe that our AIP appropriately focuses our NEOs on shorter-term (one-year) financial metrics while our LTIP emphasizes long-term stockholder value creation (i.e., three-year TSR outperformance). For 2021,2022, Mr. Sotos’ target LTIP award was 280%315% of his base salary and Messrs. PlotkinMs. Rubenstein and Mr. Malcarney’s target LTIP awards were 125% of their respective base salaries.salaries, and Mr. Plotkin’s target LTIP award was 150% of his base salary. Mr. Sotos’ target LTIP award increased from 264% in 2020 to 280% in 2021 to 315% in 2022 to recognize his performance and Mr. Malcarney'sbetter align his total direct compensation with the market median. Ms. Rubenstein’s target LTIP award increased from 100%75% in 20202021 to 125% in 2021.2022 and Mr. Plotkin’s target LTIP award increased from 125% in 2021 to 150% in 2022. These changes were made in connection with promotional matters and intended to recognize their performance and better align their total direct compensation with the market median. The above mix of long-term incentive compensation applied to all NEOs for 2021.2022. Mr. Plotkin’s outstanding RPSUs and RSUs were forfeited as of the time of his resignation in August 2022.
Relative Performance Stock Units
Each RPSU represents the potential to receive one share of Class C common stock, as adjusted, based on the Company’s TSR performance ranked against the TSR performance of a comparator group of similar companies (the “Performance Peer Group”) after the completion of a three-year performance period. Relative measures are designed to normalize for externalities, ensuring the program appropriately reflects management’s impact on the Company’s TSR by including peer companies that the Compensation Committee believes are similarly impacted by market conditions.
The payout of shares of Class C common stock at the end of the three-year performance period is based on the Company’s TSR performance percentile rank compared with the TSR performance of the Performance Peer Group. To ensure a rigorous program design, the target-level payout (100% of shares granted) requires the Company to perform at the 50th percentile. To induce management to achieve greater than target-level performance in a down market, in the event that the Company’s TSR performance declines by more than 20% over the performance period, the target-level payout (100% of shares granted) will require achievement of 60th percentile performance. The Compensation Committee believes that this increased performance requirement addresses the concern that a disproportionate award may be paid in the event that our relative performance is high, but absolute performance is low.
In the event relative performance is below the 25th percentile, the award is forfeited. In the event relative performance is between the 25th percentile and the 50th percentile (or the 60th percentile if our TSR performance declines by more than 20% over the performance period), payouts will be based on an interpolated calculation. In the event relative performance reaches the 50th percentile (or the 60th percentile as described above), 100% of the award will be paid. In the event relative performance is between the 50th percentile (or the 60th percentile as described above) and the 75th percentile, payouts will be based on an interpolated calculation. In the event that relative performance is at or above the 75th percentile, a maximum payout of 150% of the target will be paid with respect to RPSU awards granted in 2021. Beginning with respect to RPSUs granted in 2018 and continuing for grants of 2021 RPSUs, the maximum payout was (and remains) changed from 200% to 150%. As noted below, the RPSUs granted in 2019 vested at 150% of target based2022. Based on the Company’s TSR performance ranked against the TSR performance of the Performance Peer Group.Group over the three year performance period ending on December 31, 2022, the RPSUs granted in 2020 will vest on April 15, 2023 at 150% of target.
The table below illustrates the design of our RPSUs in 2021.2022.
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Performance Targets | | Performance Requirement | | Payout Opportunity | |
| Maximum | | 75th percentile or above | | 150% | |
| Target | | Standard Target: 50th percentile | | Modified Target: 60th percentile (less than −20% absolute TSR) | | 100% | |
| Threshold | | 25th percentile | | 25% | |
| Below Threshold | | Below 25th percentile | | 0% | |
Restricted Stock Units
Each RSU represents the right to receive one share of our Class C common stock after the completion of the vesting period. The RSUs granted to the NEOs in 20212022 vest ratably, meaning that one‑third of the award vests each year on the anniversary of the grant date, over a three‑year period.
Dividend Equivalent Rights (DERs)
In connection with awards of both RPSUs and RSUs, each NEO also receives DERs, which accrue with respect to the award to which they relate. Accrued DERs are only paid out to the extent that the shares of Class C common stock underlying each award become vested and deliverable to the NEO. Accrued DERs are paid at the same time such shares are delivered to the NEO. Accordingly, DERs are forfeited if the underlying shares are forfeited.
Clawbacks
The Company has a “clawback” policy with regard to awards made under the AIP and LTIP in the case of a material financial restatement, including a restatement resulting from employee misconduct, or in the case of fraud, embezzlement or other serious misconduct that is materially detrimental to the Company. The Compensation Committee retains discretion regarding application of the policy. The policy is incremental to other remedies that are available to the Company. In addition to our “clawback” policy, if the Company is required to restate its earnings as a result of noncompliance with a financial reporting requirement due to misconduct, under the Sarbanes‑Oxley Act of 2002 (“SOX”), the CEO and the CFO would also be subject to a “clawback,” as required by SOX.
Benefits
All of our NEOs are eligible to participate in the same retirement, life insurance, health and welfare plans.plans as other employees. To generally support more complicated financial planning and estate planning matters, NEOs are eligible for reimbursement of annual tax return preparation, tax advice, financial planning and estate planning expenses. Mr. Sotos is eligible for a maximum reimbursement of $12,000 per year and the remaining NEOs are eligible for a maximum reimbursement of $3,000 per year.
Potential Severance and Change‑In‑Control Benefits
Each NEO’s RPSU and RSU award agreements under the LTIP provide for certain treatment in the event of such NEO’s termination of employment under certain circumstances, including in connection with a change-in-control. Additionally, Mr. Sotos, pursuant to his amended and restated employment agreement (as described below), and the remaining NEOs, pursuant to the Company’s Executive Change-in-Control and General Severance Plan (the “CIC Plan”) as well as pursuant to the Compensation Committee’s discretion under the AIP, are entitled to additional severance payments and benefits in the event of termination of employment under certain circumstances, including following a change-in-control.
Change-in-control arrangements are considered a market practice among many publicly held companies. Most often, these arrangements are utilized to encourage executives to remain with the company during periods of extreme job uncertainty and to ensure that any potential transaction is thoroughly and objectively evaluated. In order to enable a smooth transition during an interim period, change-in-control arrangements provide a defined level of security for the executive and the company, enabling a more seamless implementation of a particular merger, acquisition or asset sale or purchase, and subsequent integration. In addition, such agreements include restrictive covenants, such as non-compete, non-solicitation and confidentiality provisions that protect the interests of the Company.
For a more detailed discussion, including the quantification of potential payments, please see the section entitled “Severance and Change-in-Control” following the executive compensation tables below.
Other Matters
Stock Ownership Guidelines
The Compensation Committee and the Board require the CEO to hold Company stock with a value equal to 5.0 times his base salary until his separation from the Company. Our other NEOs (i.e., NEOs other than the CEO)Executive Vice Presidents are required to hold Company stock with a value equal to 3.0 times their base salary until their separation from the Company. Senior Vice Presidents are required to hold Company stock with a value equal to 2.0 times their base salary until their separation from the Company. Personal holdings and vested awards count towards the ownership multiple. Beginning in 2022, unvested RSUs also count towards the ownership multiple. This change in determining attainment of the ownership multiple was implemented after reviewing the compensation practices of Compensation Peer Group Companies. Although NEOs are not required to make purchases of our common stock to meet their target ownership multiple, NEOs are restricted from divesting any securities until such ownership multiples are attained, except in the event of hardship or to make a required tax payment, and they must maintain their ownership multiple after any such transactions. Once met, they must maintain their ownership multiple during their service. The current target stock ownership for NEOs as of February 18, 2022,January 31, 2023 is shown below. All of our NEOs met or exceeded their stock ownership guidelines as of February 18, 2022.January 31, 2023, or in the case of Mr. Plotkin, as of the date of his separation from the Company.
| | | | | | | | | | | | | | | |
| Named Executive Officer | | Target Ownership Multiple | | | Actual Ownership Multiple |
| Christopher S. Sotos | | 5.0x | | | 23.7x23.6x |
Chad PlotkinSarah Rubenstein(1)
| | 3.0x2.0x | | | 8.7x3.3x |
| Kevin P. Malcarney | | 3.0x | | | 6.1x7.4x |
| Chad Plotkin | | 3.0x | | | 9.3x(2) |
| | | | | |
(1) Ms. Rubenstein was promoted to Senior Vice President and Chief Accounting Officer in January 2022 and appointed as the principal financial officer for the Company in August 2022.
(2) Reported for Mr. Plotkin as of the date of his voluntary resignation from his employment with the Company in August 2022.
Tax and Accounting Considerations
Section 162(m) of the Internal Revenue Code (the “Code”) precludes Clearway, Energy Inc., as a public company, from taking a tax deduction for individual compensation to certain of our executive officers in excess of $1 million, subject to certain exemptions. Prior to 2018, the exemptions included an exclusion of performance-based compensation within the meaning of Section 162(m) of the Code (“Section 162(m)”). The Tax Cuts and Jobs Act, enacted in December 2017, however, amended Section 162(m) and eliminated the exclusion of performance-based compensation from the $1 million limit, subject to certain exemptions. The Compensation Committee believes tax deductibility of compensation is an important consideration and continues to consider the implications of legislative changes to Section 162(m). However, the Compensation Committee also believes that it is important to retain flexibility in designing compensation programs, and as a result, has not adopted a policy that any particular amount of compensation must be deductible to the Company under Section 162(m).
The Compensation Committee also takes into account tax consequences to NEOs in designing the various elements of our compensation program, such as designing the terms of awards to defer immediate income recognition under Section 409A of the Code. The Compensation Committee remains informed of, and takes into account, the accounting implications of its compensation programs. However, the Compensation Committee approves programs based on their total alignment with our strategy and long‑term goals.
Compensation Tables
Summary Compensation Table
Fiscal Year Ended December 31, 20212022
| | Name and Principal Position | Name and Principal Position | | Year | | Salary ($)(1) | | Bonus ($) | | Stock Awards ($)(2) | | Option Awards ($) | | Non‑Equity Incentive Plan Compensation ($)(3) | | Change in Pension Value and Nonqualified Deferred Compensation Earnings ($) | | All Other Compensation ($)(4) | | Total ($) | Name and Principal Position | | Year | | Salary ($)(1) | | Bonus ($) | | Stock Awards ($)(2) | | Option Awards ($) | | Non‑Equity Incentive Plan Compensation ($)(3) | | Change in Pension Value and Nonqualified Deferred Compensation Earnings ($) | | All Other Compensation ($)(4) | | Total ($) |
| Christopher S. Sotos | Christopher S. Sotos | | 2021 | | 638,260 | | | — | | | 1,535,147 | | | — | | | 899,312 | | | — | | | 19,790 | | | 3,092,509 | | Christopher S. Sotos | | 2022 | | 659,682 | | | — | | | 1,951,273 | | | — | | | 725,069 | | | — | | | 12,200 | | | 3,348,224 | |
| President and Chief | President and Chief | | 2020 | | 634,500 | | | — | | | 1,900,423 | | | — | | | 699,534 | | | — | | | 14,111 | | | 3,248,568 | | President and Chief | | 2021 | | 638,260 | | | — | | | 1,535,147 | | | — | | | 899,312 | | | — | | | 19,790 | | | 3,092,509 | |
| Executive Officer | Executive Officer | | 2019 | | 606,304 | | | — | | | 1,527,522 | | | — | | | 906,235 | | | — | | | 14,882 | | | 3,054,943 | | Executive Officer | | 2020 | | 634,500 | | | — | | | 1,900,423 | | | — | | | 699,534 | | | — | | | 14,111 | | | 3,248,568 | |
| | Chad Plotkin | | 2021 | | 396,954 | | | — | | | 426,560 | | | — | | | 335,586 | | | — | | | 14,600 | | | 1,173,700 | | |
| Senior Vice President | | 2020 | | 394,615 | | | — | | | 559,631 | | | — | | | 281,551 | | | — | | | 14,169 | | | 1,249,966 | | |
| and Chief Financial | | 2019 | | 378,731 | | | — | | | 475,020 | | | — | | | 338,170 | | | — | | | 15,200 | | | 1,207,121 | | |
| Officer | | |
| Sarah Rubenstein | | Sarah Rubenstein | | 2022 | | 324,197 | | | — | | | 378,417 | | | — | | | 177,125 | | | — | | | 12,200 | | | 891,939 | |
| Senior Vice President and | | Senior Vice President and | | 2021 | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Chief Accounting Officer | | Chief Accounting Officer | | 2020 | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | Kevin P. Malcarney | Kevin P. Malcarney | | 2021 | | 323,991 | | | — | | | 348,772 | | | — | | | 274,368 | | | — | | | 12,550 | | | 959,681 | | Kevin P. Malcarney | | 2022 | | 398,461 | | | — | | | 465,703 | | | — | | | 283,400 | | | — | | | 12,850 | | | 1,160,414 | |
| Senior Vice President, | Senior Vice President, | | 2020 | | 317,885 | | | — | | | 362,301 | | | — | | | 151,889 | | | — | | | 10,550 | | | 842,625 | | Senior Vice President, | | 2021 | | 323,991 | | | — | | | 348,772 | | | — | | | 274,368 | | | — | | | 12,550 | | | 959,681 | |
| General Counsel and | General Counsel and | | 2019 | | 300,000 | | | — | | | 300,019 | | | — | | | 170,568 | | | — | | | 11,077 | | | 781,664 | | General Counsel and | | 2020 | | 317,885 | | | — | | | 362,301 | | | — | | | 151,889 | | | — | | | 10,550 | | | 842,625 | |
| Corporate Secretary | Corporate Secretary | | — | | | Corporate Secretary | |
| Chad Plotkin(5) | | Chad Plotkin(5) | | 2022 | | 278,219 | | | — | | | 642,691 | | | — | | | — | | | — | | | 77,372 | | | 998,282 | |
| Executive Vice President | | Executive Vice President | | 2021 | | 396,954 | | | — | | | 426,560 | | | — | | | 335,586 | | | — | | | 14,600 | | | 1,173,700 | |
| and Chief Financial Officer | | and Chief Financial Officer | | 2020 | | 394,615 | | | — | | | 559,631 | | | — | | | 281,551 | | | — | | | 14,169 | | | 1,249,966 | |
|
(1) Reflects base salary earnings.
(2) Reflects the grant date fair value determined in accordance with the Financial Accounting Standards Board Accounting Standards Codification Topic 718, Comparison — Stock Compensation. Clearway Energy, Inc. uses the Company’s Class C common stock price on the date of grant as the fair value of the Company’s RSUs. The fair value of RPSUs is estimated on the date of grant using a Monte Carlo simulation model. Prior to 2020, the number of RPSUs granted was based on the fair value of RPSUs estimated on the date of grant using a Monte Carlo simulation model. Beginning with awards granted in 2020, the number of RPSUs granted is based on the 10-day average closing price of the Company’s Class C common stock ending on the date of grant. This change in determining the number of RPSUs granted was implemented after reviewinggrant, which is intended to more closely reflect the compensation practices of the Compensation Peer Group companies. For RPSUs granted in 2021,2022, if the maximum level of performance is achieved, the fair value will be approximately $1,431,084$1,889,849 for Mr. Sotos, $397,644$366,500 for Ms. Rubenstein and $451,050 for Mr. Plotkin and $325,119 for Mr. Malcarney.
(3) The amounts shown in this column represent the annual incentive bonuses paid to the NEOs. Further information regarding the annual incentive bonuses is included in the “2021“2022 Annual Incentive Bonuses” section of this CD&A.
(4) The amounts provided in the All Other Compensation column represent the additional benefits payable by the Company and include insurance benefits; the employer match under the Company’s 401(k) plan; financial counseling services up to $12,000 per year for Mr. Sotos and up to $3,000 per year for all other NEOs, not including the financial advisor’s travel or out-of-pocket expenses; legal fees incurred by Mr. Sotos in 2021 in connection with reviewing and finalizing his amended and restated employment agreement; and when applicable, the Company’s discretionary contribution to the 401(k) plan.plan, as well as, a payout upon termination of accrued but unused paid time off for Mr. Plotkin. The following table identifies the additional compensation for each NEO.
| | Name | Name | | Year | | Life and Disability Insurance Reimbursement ($) | | Financial Advisor Services ($) | | 401(k) Employer Matching Contribution ($) | | | Legal Fees ($) | | Total ($) | Name | | Year | | Financial Advisor Services ($) | | 401(k) Employer Matching Contribution ($) | | | Legal Fees ($) | | PTO Supplemental Payout ($) | | Total ($) |
| Christopher S. Sotos | Christopher S. Sotos | | 2021 | | — | | | — | | | 11,600 | | | | 8,190 | | | 19,790 | | Christopher S. Sotos | | 2022 | | — | | | 12,200 | | | | — | | | — | | | 12,200 | |
| | 2020 | | — | | | 2,711 | | | 11,400 | | | | — | | | 14,111 | | | 2021 | | — | | | 11,600 | | | | 8,190 | | | — | | | 19,790 | |
| | 2019 | | 1,000 | | | 2,682 | | | 11,200 | | | | — | | | 14,882 | | | 2020 | | 2,711 | | | 11,400 | | | | — | | | — | | | 14,111 | |
| Chad Plotkin | | 2021 | | — | | | 3,000 | | | 11,600 | | | | — | | | 14,600 | | |
| Sarah Rubenstein | | Sarah Rubenstein | | 2022 | | — | | | 12,200 | | | | — | | | — | | | 12,200 | |
| | 2020 | | — | | | 3,000 | | | 11,169 | | | | — | | | 14,169 | | | 2021 | | — | | | — | | | | — | | | — | | | — | |
| | 2019 | | 1,000 | | | 3,000 | | | 11,200 | | | | — | | | 15,200 | | | 2020 | | — | | | — | | | | — | | | — | | | — | |
| Kevin P. Malcarney | Kevin P. Malcarney | | 2021 | | — | | | 950 | | | 11,600 | | | | — | | | 12,550 | | Kevin P. Malcarney | | 2022 | | 650 | | | 12,200 | | | | — | | | — | | | 12,850 | |
| | 2020 | | — | | | — | | | 10,550 | | | | — | | | 10,550 | | | 2021 | | 950 | | | 11,600 | | | | — | | | — | | | 12,550 | |
| | 2019 | | — | | | — | | | 11,077 | | | | — | | | 11,077 | | | 2020 | | — | | | 10,550 | | | | — | | | — | | | 10,550 | |
| Chad Plotkin | | Chad Plotkin | | 2022 | | — | | | 12,200 | | | | — | | | 65,172 | | | 77,372 | |
| | | 2021 | | 3,000 | | | 11,600 | | | | — | | | — | | | 14,600 | |
| | | 2020 | | 3,000 | | | 11,169 | | | | — | | | — | | | 14,169 | |
|
Grants of Plan‑Based Awards
Fiscal Year Ended December 31, 20212022
| | | Estimated Possible Payouts Under Non‑Equity Incentive Plan Awards | | Estimated Future Payouts Under Equity Incentive Plan Awards | | All Other Stock Awards: Number of Shares of Stock | | Grant Date Fair Value of Stock and Option | | Estimated Possible Payouts Under Non‑Equity Incentive Plan Awards | | Estimated Future Payouts Under Equity Incentive Plan Awards | | All Other Stock Awards: Number of Shares of Stock | | Grant Date Fair Value of Stock and Option |
| Name | Name | | Award Type | | Grant Date | | Approval Date | | Threshold ($)(1) | Target ($)(2) | Maximum ($)(3) | | Threshold (#) | Target (#) | Maximum (#) | | or Units (#) | | Awards ($)(4) | Name | | Award Type | | Grant Date | | Approval Date | | Threshold ($)(1) | Target ($)(2) | Maximum ($)(3) | | Threshold (#) | Target (#) | Maximum (#) | | or Units (#) | | Awards ($)(4) |
| Christopher S. Sotos | Christopher S. Sotos | | AIP | | — | | | — | | | 314,665 | | 629,330 | | 1,258,660 | | | — | | — | | — | | | — | | | | Christopher S. Sotos | | AIP | | — | | | — | | | 332,601 | | 665,201 | | 1,330,402 | | | — | | — | | — | | | — | | | — | |
| | RPSU | | 4/15/2021 | | 2/19/2021 | | — | | — | | — | | | 10,330 | | 41,319 | | 61,979 | | | — | | | 954,056 | | | RPSU | | 4/15/2022 | | 2/22/2022 | | — | | — | | — | | | 9,902 | | 39,607 | | 59,411 | | | — | | | 1,259,899 | |
| | RSU | | 4/15/2021 | | 2/19/2021 | | — | | — | | — | | | — | | — | | — | | | 20,233 | | 581,092 | | | RSU | | 4/15/2022 | | 2/22/2022 | | — | | — | | — | | | — | | — | | — | | | 20,192 | | | 691374 |
| Chad Plotkin | | AIP | | — | | | — | | | 117,420 | 234,840 | 469,680 | | — | | — | | — | | | — | | | |
| Sarah Rubenstein | | Sarah Rubenstein | | AIP | | — | | | — | | | 81,250 | | 162,500 | | 325,000 | | | — | | — | | — | | | — | | | — | |
| | RPSU | | 4/15/2021 | | 2/19/2021 | | — | | — | | — | | | 2,870 | | 11,481 | 17,222 | | — | | | 265,096 | | | RPSU | | 4/15/2022 | | 2/22/2022 | | — | | — | | — | | | 1,920 | | 7,681 | | 11,522 | | | — | | | 244,333 | |
| | RSU | | 4/15/2021 | | 2/19/2021 | | — | | — | | — | | | — | | — | | — | | | 5,622 | | 161,464 | | | RSU | | 4/15/2022 | | 2/22/2022 | | — | | — | | — | | | — | | — | | — | | | 3,916 | | | 134,084 | |
| Kevin P. Malcarney | Kevin P. Malcarney | | AIP | | — | | | — | | | 96,000 | | 192,000 | 384,000 | | — | | — | | — | | | — | | | Kevin P. Malcarney | | AIP | | — | | | — | | | 130,000 | | 260,000 | | 520,000 | | | — | | — | | — | | | — | | | — | |
| | RPSU | | 4/15/2021 | | 2/19/2021 | | — | | — | | — | | | 2,347 | 9,387 | 14,081 | | — | | | 216,746 | | | RPSU | | 4/15/2022 | | 2/22/2022 | | — | | — | | — | | | 2,363 | | 9,453 | | 14,180 | | | — | | | 300,700 | |
| | RSU | | 4/15/2021 | | 2/19/2021 | | — | | — | | — | | | — | | — | | — | | | 4,597 | | 132,026 | | | RSU | | 4/15/2022 | | 2/22/2022 | | — | | — | | — | | | — | | — | | — | | | 4,819 | | | 165,003 | |
Chad Plotkin(5) | | Chad Plotkin(5) | | AIP | | — | | | — | | | 161,000 | | 322,000 | | 644,000 | | | — | | — | | — | | | — | | | — | |
| | | RPSU | | 4/15/2022 | | 2/22/2022 | | — | | — | | — | | | 3,261 | | 13,045 | | 19,568 | | | — | | | 414,961 | |
| | | RSU | | 4/15/2022 | | 2/22/2022 | | — | | — | | — | | | — | | — | | — | | | 6,651 | | | 227,730 | |
(1) Threshold non-equity incentive plan awards include annual incentive plan threshold payments, as presented in the CD&A.
(2) Target non-equity incentive plan awards include annual incentive plan target payments, as presented in the CD&A.
(3) Maximum non-equity incentive plan awards include annual incentive plan maximum payments, as presented in the CD&A.
(4) Reflects the grant date fair value determined in accordance with the Financial Accounting Standards Board Accounting Standards Codification Topic 718, Comparison—Stock Compensation. The Company uses the Class C common stock price on the date of grant as the fair value of the Company’s RSUs. The fair value of RPSUs is estimated on the date of grant using a Monte Carlo simulation model. For the years preceding 2020, the number of RPSUs granted was based on the fair value of RPSUs was estimated on the date of grant using a Monte Carlo simulation model. Beginning with awards madegranted in 2020, the fair valuenumber of RPSUs granted is based on the 10-day average closing price of the Company’s Class C common stock ending on the date of grant. This change in determining fair value of the RPSUs was implemented after reviewing the compensation practices of Compensation Peer Group companies.
Outstanding Equity Awards at Fiscal Year End
Fiscal Year Ended December 31, 20212022
| | | Option Awards | | Stock Awards | | Option Awards | | Stock Awards |
| | Number of | | Number of | | | Number | | Market Value | | Equity Incentive Plan Awards | | Number of | | Number of | | | Number | | Market Value | | Equity Incentive Plan Awards |
| Name | Name | | Securities Underlying Unexercised Options (#) Exercisable | | Securities Underlying Unexercised Options (#) Unexercisable | | Option Exercise Price ($) | | Option Expiration Date | | of Shares or Units of Stock that Have Not Vested (#) | | of Shares or Units of Stock that Have Not Vested ($) | | Number of Unearned Shares that Have Not Vested (#)(1) | | Market Value of Unearned Shares that Have Not Vested ($)(1) | Name | | Securities Underlying Unexercised Options (#) Exercisable | | Securities Underlying Unexercised Options (#) Unexercisable | | Option Exercise Price ($) | | Option Expiration Date | | of Shares or Units of Stock that Have Not Vested (#) | | of Shares or Units of Stock that Have Not Vested ($) | | Number of Unearned Shares that Have Not Vested (#)(1) | | Market Value of Unearned Shares that Have Not Vested ($)(1) |
| Christopher S. Sotos | Christopher S. Sotos | | — | | | — | | | — | | | — | | | 52,227(2) | | 1,881,739 | | 166,383(3) | | 5,994,779 | Christopher S. Sotos | | — | | | — | | | — | | | — | | | 45,836(2) | | 1,460,793 | | 149,062(3) | | 4,750,606 |
| Chad Plotkin | | — | | | — | | | — | | | — | | | 15,215(4) | | 548,196 | | 49,317(5) | | 1,776,892 | |
| Sarah Rubenstein | | Sarah Rubenstein | | — | | | — | | | — | | | — | | | 12,735(4) | | 405,864 | | 7,916(5) | | 252,283 |
| Kevin P. Malcarney | Kevin P. Malcarney | | — | | | — | | | — | | | — | | | 10,783(6) | | 388,511 | | 33,637(7) | | 1,211,941 | Kevin P. Malcarney | | — | | | — | | | — | | | — | | | 10,115(6) | | 322,365 | | 32,001(7) | | 1,019,872 |
Chad Plotkin(8) | | Chad Plotkin(8) | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
|
(1) Assumes achievement at target award level for 2019, 2020, 2021 and 20212022 RPSU awards as discussed in the CD&A.
(2) This amount represents 9,78922,819 RSUs and 1,397 DERs that vested on January 2, 2022, 16,066 RSUs and 950 DERs that will vest on April 15, 2022, 16,096 RSUs and 9531,868 DERs that will vest on April 15, 2023, and 6,75813,482 RSUs and 218715 DERs that will vest on April 15, 2024.2024, and 6,745 RSUs and 207 DERs that will vest on April 15, 2025.
(3) This amount represents 54,671 RPSUs and 7,802 DERs that vested on January 2, 2022, 56,792 RPSUs and 4,4627,014 DERs that will vest on April 15, 2023, 41,319 RPSUs and 41,3193,114 DERs that will vest on April 15, 2024, and 39,607 RPSUs and 1,216 DERs that will vest on April 15, 2025.
(4) This amount represents 5,115 RSUs and 391 DERs that will vest on April 15, 2023, 1,711 RSUs and 169 DERs that will vest on November 2, 2023, 3,775 RSUs and 226 DERs that will vest on April 15, 2024, and 1,308 RSUs and 40 DERs that will vest on April 15, 2025.
(5) This amount represents 7,681 RPSUs and 235 DERs that will vest on April 15, 2025.
(6) This amount represents 4,778 RSUs and 373 DERs that will vest on April 15, 2023, 3,141 RSUs and 164 DERs that will vest on April 15, 2024, and 1,610 RSUs and 49 DERs that will vest on April 15, 2025. Amounts do not include shares withheld for payment of taxes due to retirement eligibility.
(7) This amount represents 10,827 RPSUs and 1,337 DERs that will vest on April 15, 2024. On January 2, 2022, the 2019 RPSU award vested at 150% of target based on the Company’s TSR performance ranked against the TSR performance of the Performance Peer Group.
(4) This amount represents 3,045 RSUs2023, 9,387 RPSUs and 434 DERs that vested on January 2, 2022, 4,619 RSUs and 275707 DERs that will vest on April 15, 2022, 4,628 RSUs2024, and 2769,453 RPSUs and 290 DERs that will vest on April 15, 2023, and 1,878 RSUs and 60 DERs that will vest on April 15, 2024.2025.
(5) This amount represents 17,001 RPSUs and 2,426 DERs that vested on January 2, 2022, 16,724 RPSUs and 1,314 DERs that will vest on April 15, 2023, and 11,481 RPSUs and 371 DERs that will vest on April 15, 2024. On January 2, 2022,(8) Mr. Plotkin voluntarily resigned from his employment with the 2019 RPSU award vested at 150% of target based on the Company’s TSR performance ranked against the TSR performance of the Performance Peer Group.
(6) This amount represents 1,923 RSUs and 274 DERs that vested on January 2, 2022, 3,309 RSUs and 188 DERs that will vest on April 15, 2022, 3,315 RSUs and 189 DERs that will vest on April 15, 2023, and 1,536 RSUs and 49 DERs that will vest on April 15, 2024.
(7) This amount represents 10,738 RPSUs and 1,532 DERs that vested on January 2, 2022, 10,827 RPSUs and 850 DERs that will vest on April 15, 2023, and 9,387 RPSUs and 303 DERs that will vest on April 15, 2024. On January 2, 2022, the 2019 RPSU award vested at 150% of target based on the Company’s TSR performance ranked against the TSR performance of the Performance Peer Group.Company in August 2022.
Option Exercises and Stock Vested
Fiscal Year Ended December 31, 20212022
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Option Awards | | Stock Awards |
| Name | | Number of Shares Acquired on Exercise (#) | | Value Realized on Exercise ($) | | Number of Shares Acquired on Vesting (#)(1) | | Value Realized on Vesting ($)(3)(2) |
| Christopher S. Sotos | | — | | | — | | | 98,461122,092(2)(3)
| | 3,112,6374,368,298 | |
Chad PlotkinSarah Rubenstein | | — | | | — | | | 28,0406,668(4)
| | 886,183227,324 | |
| Kevin P. Malcarney | | — | | | — | | | 7,78424,283(5)
| | 242,631868,759 | |
Chad Plotkin(7) | | — | | | — | | | 37,567(6) | | 1,344,742 | |
(1) Includes shares and DERs that vested pursuant to underlying awards and converted to Class C common stock in 2021.2022.
(2) Represents 7,102 RSUs, 59,399 RPSUs The values are based on the December 31, 2021 Class C common stock closing share price of $36.03 for awards and 11,532 DERs that vested on January 2, 20212022, the April 14, 2022 Class C common stock closing share price of $34.24 for awards and DERs that vested on April 15, 2022, the October 14, 2022 Class C common stock closing share price of $31.26 for awards and DERs that vested on October 15, 2022, the November 2, 2022 Class C common stock closing share price of $34.91 for awards and DERs that vested on November 2, 2022. The values for retirement eligible NEOs are based on the Class C common stock closing share price on the dates the awards became eligible for continued vesting and shares and DERs were withheld to cover certain tax withholding obligations.
(3) Represents 9,789 RSUs, 82,007 RPSUs and 13,100 DERs that vested on January 2, 2022 pursuant to the stock compensation awards granted on January 2, 2018. Represents 9,759 RSUs and 923 DERs that vested on January 2, 2021 pursuant to the stock compensation award granted on January 2, 2019. Represents 9,329 RSUs and 417839 DERs that vested on April 15, 20212022 pursuant to the stock compensation award granted on April 15, 2020. Represents 6,737 RSUs and 291 DERs that vested on April 15, 2022 pursuant to the stock compensation award granted on April 15, 2021.
(3) The values are based(4) Represents 689 RSUs and 92 DERs that vested on December 31, 2020 Class C commonOctober 15, 2022 pursuant to the stock closing share price of $31.93 for awardscompensation award granted on October 15, 2019. Represents 1,343 RSUs and 120 DERs that vested on April 15, 2022 pursuant to the stock compensation award granted on April 15, 2020. Represents 1,706 RSUs and 149 DERs that vested on November 2, 2022 pursuant to the stock compensation award granted on November 2, 2020. Represents 2,463 RSUs and 106 DERs that vested on April 15, 2022 pursuant to the stock compensation award granted on April 15, 2021.
(5) Represents 1,923 RSUs, 16,107 RPSUs and 2,572 DERs that vested on January 2, 2021. The values are based on April 15, 2021 Class C common stock closing share price of $28.72 for awards and DERs that vested on April 15, 2021.
(4) Represents 1,989 RSUs, 16,632 RPSUs and 3,228 DERs that vested on January 2, 20212022 pursuant to the stock compensation awards granted on January 2, 2018.2019. Represents 3,0351,615 RSUs and 287 DERs that vested on January 2, 2021 pursuant to the stock compensation award granted on January 2, 2019. Represents 2,747 RSUs and 122145 DERs that vested on April 15, 20212022 pursuant to the stock compensation award granted on April 15, 2020.
(5) Represents 3,3231,530 RSUs and 506 DERs that vested on January 2, 2021 pursuant to the stock compensation award granted on May 11, 2018. Represents 1,917 RSUs and 181 DERs that vested on January 2, 2021 pursuant to the stock compensation award granted on January 2, 2019. Represents 1,778 RSUs and 7966 DERs that vested on April 15, 20212022 pursuant to the stock compensation award granted on April 15, 2020.2021. Represents 305 shares and 20 DERs that were withheld to cover certain tax obligations in 2022 due to awards becoming eligible for continued vesting in the event of the NEO’s retirement.
(7) Mr. Plotkin voluntarily resigned from his employment with the Company in August 2022.
Employment Agreements
The Company has not entered into employment agreements with any executive officers other than Mr. Sotos.
On September 23, 2021, the Company and Mr. Sotos entered into an agreement amending and restating Mr. Sotos'Sotos’ employment agreement, dated as of May 6, 2016, as previously amended, pursuant to which Mr. Sotos continues to serve as the Company’s President and CEO for a new term that began on September 23, 2021 (the “Effective Date”). Under this amended and restated employment agreement, the term of Mr. Sotos'Sotos’ employment will continue until the earlier of the date that his employment is terminated by either party or December 31, 2024; provided that such employment period will automatically renew on the same terms and conditions for additional one-year terms unless either party provides the other party with written notice of its election not to renew the then-current employment period at least 90 days before such period'speriod’s expiration date. The amended and restated employment agreement entitled Mr. Sotos to an annual base salary of $629,330 for the period beginning on the Effective Date and ending on December 31, 2021. For each annual period thereafter, our Board will determine whether to increase Mr. Sotos’ annual base salary. For the 2022 fiscal year, the Board increased Mr. Sotos’ annual base salary to $665,201. The amended and restated employment agreement further provides that beginning with the 2021 fiscal year, Mr. Sotos is eligible to receive an annual bonus at a target amount equal to 100% of base salary (i.e., AIP bonus), with it being understood that such percentage may be increased by the Company from time to time, in each case based on achievement of criteria determined by the Board with input from Mr. Sotos. The maximum award opportunity each year is 200% of the target amount. The amended and restated employment agreement further provides that Mr. Sotos is eligible to participate in the LTIP, on such terms as are set forth in the plan. Mr. Sotos’ target LTIP award for the 20212022 fiscal year was approximately 280%315% of base salary.
In addition to the compensation and benefits described above, as well as paid vacation and director and officer liability insurance, the amended and restated employment agreement provides that Mr. Sotos will receive the following:
•Reimbursement for annual tax return preparation expenses and tax advice and financial planning, up to a maximum of $12,000 per year, and reimbursement for legal fees incurred in connection with reviewing and finalizing his amended and restated employment agreement, up to a maximum of $12,000;year;
•Eligibility to participate in the Company’s retirement plans, health and welfare plans, and disability insurance plans under the same terms, and to the same extent, as other senior management of the Company; and
•Reimbursement for the costs of litigation or other disputes incurred in asserting any claims under the amended and restated employment agreement, unless the court finds in favor of the Company.
The amended and restated employment agreement also provided Mr. Sotos with a reimbursement for legal fees incurred in connection with reviewing and finalizing his amended and restated employment agreement, up to a maximum of $12,000 (as noted above, Mr. Sotos received a reimbursement of $8,190 in 2021 under this provision of his employment agreement).The amended and restated employment agreement alsofurther entitles Mr. Sotos to certain severance payments and benefits in the event his employment terminates under certain circumstances. These severance payments and benefits are described and quantified under the section “Severance and Change‑in‑Control” below. In addition, under the amended and restated employment agreement, the Company has agreed to indemnify Mr. Sotos against any claims arising as a result of his position with the Company to the fullest extent permitted by the Company'sCompany’s certificate of incorporation, bylaws or Board resolutions or, if greater, Delaware law.
The amended and restated employment agreement includes non‑competition and non‑solicitation restrictions on Mr. Sotos during the term of his employment and for one year after his termination of employment. The amended and restated employment agreement also includes confidentiality, indemnification obligations and intellectual property restrictions and an obligation for Mr. Sotos to cooperate with the Company in the event of any internal, administrative, regulatory, or judicial proceeding. The provisions of the amended and restated employment agreement may only be waived with the written consent of the Company and Mr. Sotos.
Severance and Change‑In‑Control
Each NEO’s RPSU and RSU award agreements under the LTIP provide for special treatment in the event of such NEO’s termination of employment under certain circumstances. Upon death or disability, an NEO’s RSUs and RPSUs will vest in full and the performance metrics with respect to the RPSUs will be deemed to be achieved at target levels. Upon retirement, an NEO’s RSUs and RPSUs will remain eligible for vesting pursuant to the award agreement as though the NEO was continuously employed by the Company throughout the relevant period; provided that retirement occurs more than 12 months following the applicable award’s grant date. Further, if an NEO’s employment is involuntarily terminated by the Company without cause (as defined in Mr. Sotos’ amended and restated employment agreement with respect to Mr. Sotos, and as defined in the LTIP with respect to the other NEOs) during the Change“Change in Control PeriodPeriod” (as defined below), (i) such NEO’s RSUs will vest in full immediately upon the later of such change in control or such termination of employment and (ii) the Compensation Committee will, pursuant to the terms and conditions of the LTIP and RPSU award agreement(s), determine the final amount payable to the NEO, if any, pursuant to his or her RPSUs. NoIn general, no RPSU or RSU that is granted to an NEO provides for accelerated vesting upon any other involuntary termination. RSUs granted to Ms. Rubenstein prior to her promotion to Senior Vice President and Chief Accounting Officer provide pro-rated vesting for certain involuntary terminations of service that occur in connection with certain significant business events. Mr. Plotkin’s outstanding RPSUs and RSUs were forfeited as of the time of his resignation in August 2022.
The “Change in Control Period” is the period commencing six months immediately prior to, and ending 1224 months (or in the case of Mr. Sotos, 24 months) immediately following, a change in control of the Company (as defined in the LTIP and Mr. Sotos’ employment agreement as applicable). Effective December 7, 2021 with respect to the LTIP and January 1, 2022 with respect to the CIC Plan, the ending date for the Change in Control Period for each of the NEOs other than Mr. Sotos was extended to 24 months immediately following a change in control of the Company (i.e., matching the existing Change of Control Period with respect to Mr. Sotos).
In addition to the above-described treatment of the equity awards, Mr. Sotos, pursuant to his amended and restated employment agreement, and the other NEOs, pursuant to the CIC Plan and in some cases, the AIP, are entitled to certain additional severance payments and benefits in the event of termination of employment under certain circumstances, including following a change‑in‑control.
Mr. Sotos’ Benefits
If Mr. Sotos’ employment is involuntarily terminated by the Company without cause or if he terminates his employment for good reason, subject to Mr. Sotos executing a release of claims, the Company agrees to provide Mr. Sotos with the following severance benefits:
•A lump sum payment equal to no less than 1.5 times Mr. Sotos’ annual base salary in effect at the time of Mr. Sotos'Sotos’ termination of employment;
•A lump sum payment equal to the bonus that Mr. Sotos would have earned if his employment had not terminated (i.e., contingent on satisfaction of the performance goals applicable to such bonus) under the then‑current bonus plan, which amount will be pro‑rated based on the number of days during the year that he was employed by the Company and paid at the time annual bonus payments are generally made to the Company'sCompany’s executive officers;
•Any unpaid bonus amount for the prior fiscal year to the extent not paid prior to the termination date; and
•Reimbursement of the portion of COBRA premiums based on the monthly premium cost that would have been paid by the Company immediately prior to Mr. Sotos'Sotos’ termination of employment for a period of 18 months after the date of termination, except that such coverage will be discontinued if Mr. Sotos becomes eligible for medical benefits from a subsequent employer or otherwise.
If Mr. Sotos’ employment is involuntarily terminated by the Company without cause or if he terminates his employment for good reason within the six months immediately prior to, or the 24 months immediately following, a change in control of the Company (i.e., the Change in Control Period with respect to Mr. Sotos), in lieu of the severance benefits set forth above, the Company will provide Mr. Sotos with the following severance benefits:
•A lump sum payment of no less than three times the sum of (a) Mr. Sotos’ base salary in effect at the time of Mr. Sotos'Sotos’ termination of employment, or if greater, at such time that is immediately prior to the change in control and (b) Mr. Sotos’ target bonus opportunity under the then-current bonus plan for the year of termination;
•A lump sum payment equal to the target bonus opportunity under the then‑current bonus plan, which amount will be pro‑rated based on the number of days during the year that he was employed by the Company;
•Any unpaid bonus amount for the prior fiscal year to the extent not paid prior to the termination date; and
•Reimbursement of the portion of COBRA premiums based on the monthly premium cost that would have been paid by the Company immediately prior to Mr. Sotos'Sotos’ termination of employment for a period of 18 months after the date of termination, except that such coverage will be discontinued if Mr. Sotos becomes eligible for medical benefits from a subsequent employer or otherwise.
If Mr. Sotos’ employment is terminated as a result of his death or disability, the Company agrees to pay him an amount equal to the target bonus opportunity for the year of termination, which amount will be pro‑rated based on the number of days during the year that Mr. Sotos’Sotos was employed by the Company. In addition, the Company will pay Mr. Sotos any unpaid bonus amount for the prior fiscal year to the extent not paid prior to the termination date.
If an excise tax under Section 4999 of the Code would be triggered by any payments under Mr. Sotos’ amended and restated employment agreement or otherwise upon a change‑in‑control, the Company will reduce such payments so that no amounts are subject to Section 4999 of the Code, if such reduction would cause the amount to be retained by Mr. Sotos to be greater than if Mr. Sotos were required to pay such excise tax.
NEO Benefits
Eligible NEOs may receive a discretionary payment of the pro-rated target bonus under the AIP in the event of such NEO’s termination of employment under certain circumstances, including upon his or her termination due to retirement or involuntary termination without cause. Such amount, if payable in the Compensation Committee’s discretion, will be pro-rated based on the number of days during the year that he or she was employed by the Company. In addition, under the CIC Plan, in the event of involuntary termination without cause, eligible NEOs are entitled to a general severance benefit equal to 1.5 times base salary payable in a lump sum amount and reimbursement for COBRA benefits continuation cost for a period of 18 months.
The CIC Plan also provides a change-in-control benefit in the event that, within six months prior to, as well as 1224 months following, a change-in-control, (as noted above, this 12-month period was changed to 24 months in the CIC Plan effective January 1, 2022), an eligible NEO’s employment is either involuntarily terminated by the Company without cause or voluntarily terminated by such NEO for good reason. Mr. Plotkin’s change-in-control benefit consistsconsisted of an amount equal to 2.99 times the sum of his base salary plus the annual target incentive for the year of termination, payable in a lump sum amount. The change-in-control benefit for Mr. Malcarney (during 2021) consistedconsists of an amount equal to 2.0 times the sum of his base salary plus the annual target incentive for the year of termination, payable in a lump sum amount. Beginning in 2022, and consistent with Mr. Malcarney's 2022 promotion from Senior Vice President to Executive Vice President (as part of such promotion, Mr. Malcarney also will continue to serve as our General Counsel and Corporate Secretary), Mr. Malcarney's change-in-control benefit has been increased, effective January 1, 2022, to an amount equal to 2.99 times the sum of his base salary plus the annual target incentive for the year of termination. Ms. Rubenstein became eligible to participate in the CIC Plan upon her promotion to Senior Vice President and Chief Accounting Officer in January 2022. The change-in-control benefit for Ms. Rubenstein consists of an amount equal to 2.0 times the sum of her base salary plus the annual target incentive for the year of termination. Prior to her promotion, Ms. Rubenstein was eligible for change-in-control and severance benefits under the Key Management Change-in-Control and General Severance Plan. All such NEOs are also eligible for an amount equal to their target bonus for the year of termination, pro-rated for the number of days during the performance period that such NEO was employed by the Company and reimbursement for all or a portion of such NEO'sNEO’s COBRA benefits continuation cost for a period of 18 months, such that the NEO maintains the same coverage level and cost, on an after-tax basis, as in effect immediately prior to his or her termination of employment.
As a condition of receiving severance or change-in-control benefits, an eligible NEO must execute a release of claims and acknowledge the restrictive covenants in the CIC Plan. Such restrictive covenants include non-competition, non-solicitation and non-disparagement covenants applicable for one year after termination, confidentiality and intellectual property obligations. The provisions of the CIC Plan may only be waived by the written consent of the Compensation Committee and the applicable NEO.
If an excise tax under Section 4999 of the Code would be triggered for an eligible NEO by any payments under the CIC Plan or otherwise upon a change-in-control, the Company will reduce such payments so that no amounts are subject to Section 4999 of the Code, if such reduction would cause the amount to be retained by such NEO to be greater than if such NEO were required to pay such excise tax.
Definition of Change-in-Control,Change-In-Control, Etc.
In general, under Mr. Sotos’ amended and restated employment agreement and the CIC Plan, a “change-in-control” occurs in the event: (a) any person or entity (with certain exceptions), becomes the direct or indirect beneficial owner of 50% or more of the Company’s then-outstanding voting or common stock or obtains the power to, directly or indirectly, vote or cause to be voted 50% or more of the Company’s capital stock entitled to vote in the election of directors, including by contract or through proxy, (b) directors serving on the Board as of a specified date cease to constitute at least a majority of the Board unless such directors are approved by a vote of at least a majority of the incumbent directors; provided that a person whose assumption of office is in connection with an actual or threatened election contest or actual or threatened solicitation of proxies including by reason of agreement intended to avoid or settle such contest shall not be considered to be an incumbent director, (c) any reorganization, merger, consolidation, sale of all or substantially all of the assets of the Company or other transaction is consummated unless the previous stockholders of the Company own more than 50% of the then-outstanding common stock and combined voting power of the company resulting from such change-in-control transaction, or (d) the stockholders approve a plan or proposal to liquidate or dissolve the Company.
An involuntary termination without “cause” means the NEO’s termination by the Company for any reason other than the NEO’s (a) conviction of, or agreement to a plea of nolo contendere to, a felony or other crime involving moral turpitude (including an indictment therefortherefore under the CIC Plan), (b) willful failure to perform his or her duties (or in Mr. Sotos'Sotos’ case, his material duties pursuant to his amended and restated employment agreement), (c) willful gross neglect or willful misconduct (including a material act of theft, fraud, malfeasance or dishonesty in connection with his or her performance of duties under the CIC Plan), or (d) breach of any written agreement between the Company or NEO, a violation of the Company’s Code of Conduct or other written policy (or in Mr. Sotos’ case, a material breach of such a written agreement or material violation of the Company'sCompany’s Code of Conduct).
A voluntary termination for “good reason” means the resignation of the NEO in the event of (a) a reduction in his or her base salary or target total compensation by more than 15%, excluding across-the-board reductions to his or her base salary or annual bonus target, or if during the Change in Control Period, any reduction of base salary or target total compensation (without regard to whether the reduction applies on an across-the-board basis), (b) a material reduction in his or her benefits under or relative level of participation in the Company’s employee benefit plans, (c) a material diminution in his or her title, authority, duties or responsibilities, (d) a relocation of his or her principal place of employment by more than 50 miles or (e) the failure of a successor to the Company to agree, in writing, to assume the CIC Plan, or in the case of Mr. Sotos, his amended and restated employment agreement, within 15 days after a merger, consolidation, sale or similar transaction. In Mr. Sotos’ case only, “good reason” also includes (i) in lieu of the event described in the preceding subclause (a), a reduction in his base salary, annual bonus target, or target long-term incentive awards by more than 15%, excluding across-the-board reductions to his base salary, annual bonus target, and/or target long-term incentive awards, or if during the period that is within the six months immediately prior to, or 24 months immediately following a change in control of the Company, any reduction of base salary, annual bonus target, or target long-term incentive awards (without regard to whether the reduction applies on an across-the-board basis), (ii) any material failure by the Company to comply with his amended and restated employment agreement, (iii) his removal from the Board, (iv) the failure to elect him to the Board during any regular election, or (v) a change in reporting structure of the Company requiring Mr. Sotos to report to anyone other than the Board.
Potential Payments Upon Termination or Change‑In‑Control
The amount of compensation payable to each NEO in each circumstance is shown in the table below, assuming that termination of employment occurred as of December 31, 2021,2022, and including payments that would have been earned as of such date. The amounts shown below do not include benefits payable under the Company’s 401(k) plan.
| | Named Executive Officer | Named Executive Officer | | Involuntary Termination Not for Cause ($) | Voluntary Termination for Good Reason ($) | | Involuntary Not for Cause or Voluntary for Good Reason Following a Change in Control ($) | | Death or Disability ($) | | Named Executive Officer | | Involuntary Termination Not for Cause ($) | Voluntary Termination for Good Reason ($) | | Involuntary Not for Cause or Voluntary for Good Reason Following a Change in Control ($) | | Death or Disability ($) | Qualified Retirement | |
| Christopher S. Sotos | Christopher S. Sotos | | 1,590,735 | | 1,590,735 | | | 12,299,344 | | | 8,505,954 | | | Christopher S. Sotos | | 1,683,534 | | 1,683,534 | | | 10,888,490 | | | 6,876,752 | | — | | |
| Chad Plotkin | | 851,363 | | — | | | 4,461,981 | | | 2,560,101 | | | |
Sarah Rubenstein(1) | | Sarah Rubenstein(1) | | 789,655 | | — | | | 1,830,963 | | | 820,750 | | — | | |
Kevin P. Malcarney | Kevin P. Malcarney | | 703,009 | | — | | | 2,303,966 | | | 1,792,637 | | | Kevin P. Malcarney | | 897,351 | | — | | | 3,613,118 | | | 1,602,367 | | 1,133,550 | | |
Chad Plotkin(3) | | Chad Plotkin(3) | | — | | — | | | — | | | — | | — | | |
(1) Ms. Rubenstein was promoted to Senior Vice President and Chief Accounting Officer in January 2022 and appointed as the principal financial officer for the Company in August 2022.
(2) Mr. Malcarney was promoted to Executive Vice President, General Counsel and Corporate Secretary in January 2022. He met the definition of Qualified Retirement in 2022 and is therefore entitled to certain payments and vesting of awards in the event he retires before they vest.
(3) Mr. Plotkin was promoted to Executive Vice President and Chief Financial Officer in January 2022. Mr. Plotkin voluntarily resigned from his employment with the Company in August 2022. Accordingly, disclosure is limited to the voluntary termination event (without good reason) that actually occurred, such that, no termination benefits were due or owing to Mr. Plotkin in connection with such voluntary termination event.
CEO Pay Ratio
As a result of the rules under the Dodd–FrankDodd-Frank Act, the SEC requires disclosure of the CEO to median employee pay ratio. The following is a reasonable estimate, prepared under applicable SEC rules, of the ratio of the annual total compensation of our CEO, Mr. Sotos, to the annual total compensation of our median employee.
For purposes of the CEO pay ratio disclosure for the prior 3 years, weWe determined that we could use in our 2022 CEO pay ratio analysis the same median employee that we identified in 2021 given that there was no change in either our employee population or our employee compensation arrangements that we believe would significantly impact our pay ratio disclosure. Pursuant toIn light of the rules under the Dodd Frank Act, we are required to reasonably identifyThermal sale that occurred in 2022, a new median employee for 2021. To reasonably identify the median employee, the Company extracted and ranked IRS Form W2 wages of all 303 employees employed as of December 31, 2021 (excluding the CEO) from the Company’s HRIS system of record.was identified in 2022. Our median employee’s annual total compensation for 20212022 was determined using the same rules that apply to reporting the compensation of our NEOs (including our CEO) in the “Total” column of the “Summary Compensation Table — 20192020 — 2021”2022” above. The following total compensation amounts were determined based on that methodology:
•The annual total compensation of the median employee for 20212022 was $106,778.$136,464.
•The annual total compensation of Mr. Sotos for 20212022 was $3,092,509.$3,348,224.
•As a result, we estimate that Mr. Sotos’ 20212022 annual total compensation was approximately 2925 times that of our median employee.
Given the different methodologies, exemptions, estimates and assumptions that various public companies use to determine an estimate of their pay ratio, the estimated ratio reported above should not be solely used as a basis for comparison between companies.
Item 12 — Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
Clearway Energy LLC Ownership
As of December 31, 2021,2022, GIP, through CEG, owned 42,738,750 of each of the Company'sCompany’s Class B units and Class D units, and Clearway, Inc. owned 34,599,64534,613,853 of the Company'sCompany’s Class A units and 81,779,02182,283,460 of the Company'sCompany’s Class C units. As of December 31, 2021,2022, Clearway, Inc., through its holdings of Class A units and Class C units, owned a 57.65%57.88% economic interest in the Company. Clearway, Inc. consolidates the results of the Company through its controlling interest as sole managing member. As of December 31, 2021, GIP,2022, CEG, through CEG'sits holdings of Class B units and Class D units, owned a 42.35%42.12% economic interest in the Company.
Clearway Energy, Inc. Ownership
Stock Ownership of Executive Officers
The following table sets forth information concerning beneficial ownership of Clearway, Inc.’s Class A and Class C common stock and combined voting power of Class A, Class B, Class C and Class D common stock for: (a) each NEO and (b) all executive officers as a group. The percentage of beneficial ownership is based on 34,599,64534,613,853 shares of Class A common stock outstanding as of February 18, 2022,January 31, 2023, and 81,869,90782,283,460 shares of Class C common stock outstanding as of February 18, 2022,January 31, 2023, and percentage of combined voting power is based on 78,584,48278,598,805 votes represented by Clearway, Inc.’s outstanding Class A, Class B, Class C and Class D common stock in the aggregate as of February 18, 2022.January 31, 2023. The percentage of beneficial ownership and the percentage of combined voting power also include any shares that such person has the right to acquire within 60 days of February 18, 2022.January 31, 2023. Unless otherwise indicated, each person has sole voting and dispositive power with respect to the shares set forth in the following table.
The address of the beneficial owners is Clearway Energy, Inc., 300 Carnegie Center, Suite 300, Princeton, New Jersey 08540.
| | | | | | | | | | | | | | | | | |
| | | Common Stock |
| Class A Common Stock | Class C Common Stock | % of |
| Executive Officers | Number(1) | % of Class A Common Stock | Number(1) | % of Class C Common Stock | Combined Voting Power(2) |
| Christopher S. Sotos | 27,100(3) | * | 248,656331,940(3)
| * | * |
Chad PlotkinSarah Rubenstein | 6,697380(4)
| * | 63,57918,532(4)
| * | * |
| Kevin P. Malcarney | 600(5) | * | 46,30067,881(5)
| * | * |
All executive officers as a
| 34,39728,080(6)
| * | 358,535418,353(6)
| * | * |
* Less than one percent of outstanding Class A common stock, Class C common stock or combined voting power, as applicable.
(1) The number of shares beneficially owned by each person or entity is determined under the rules of the SEC, and the information is not necessarily indicative of beneficial ownership for any other purpose. Under such rules, each person or entity is considered the beneficial owner of any: (a) shares to which such person or entity has sole or shared voting power or dispositive power and (b) shares that such person or entity has the right to acquire within 60 days.
(2) Represents the voting power of all of the classes of Clearway, Inc.’s common stock together as a single class. Each holder of Class A or Class B common stock is entitled to one vote for each share held. Each holder of Class C or Class D common stock is entitled to 1/100th of one vote for each share held. Holders of shares of Clearway, Inc.’s Class A, Class B, Class C and Class D common stock vote together as a single class on all matters presented to its stockholders for their vote or approval, except as otherwise provided by applicable law.
(3) Includes 95012,391 DERs to be paid in Class C common stock. Excludes 22,85420,227 RSUs, 6,97212,268 DERs and 98,11180,926 RPSUs. Each RSU represents the right to receive one share of Class C common stock upon vesting. Each RPSU represents the potential to receive Class C common stock based upon Clearway, Inc. achieving a certain level of total shareholder return relative to Clearway, Inc.’s peer group over a three-year performance period. Each DER represents the right to receive the dividends and distributions that would have otherwise been paid with respect to a share subject to a RSU or RPSU award (if such share were outstanding rather than being subject to the applicable award).
(4) Includes 275392 DERs to be paid in Class C common stock. Excludes 6,5066,794 RSUs, 2,025672 DERs and 28,2057,681 RPSUs. Each RSU represents the right to receive one share of Class C common stock upon vesting. Each RPSU represents the potential to receive Class C common stock based upon Clearway, Inc. achieving a certain level of total shareholder return relative to Clearway, Inc.’s peer group over a three-year performance period. Each DER represents the right to receive the dividends and distributions that would have otherwise been paid with respect to a share subject to a RSU or RPSU award (if such share were outstanding rather than being subject to the applicable award).
(5) Includes 1882,380 DERs to be paid in Class C common stock. Excludes 4,8514,751 RSUs, 1,3962,550 DERs and 20,21418,840 RPSUs. Each RSU represents the right to receive one share of Class C common stock upon vesting. Each RPSU represents the potential to receive Class C common stock based upon Clearway, Inc. achieving a certain level of total shareholder return relative to Clearway, Inc.’s peer group over a three-year performance period. Each DER represents the right to receive the dividends and distributions that would have otherwise been paid with respect to a share subject to a RSU or RPSU award (if such share were outstanding rather than being subject to the applicable award).
(6) Consists of the total holdings of all executive officers as a group.
Item 13 — Certain Relationships and Related Transactions, and Director Independence
Relationship with GIP and Clearway Energy, Inc.
GIP, through its ownership of CEG, indirectly owns all of Clearway, Inc.'s’s outstanding Class B common stock and Class D common stock, which represents, in the aggregate, 54.93%54.91% of the voting interest in Clearway, Inc.'s’s stock, and receives distributions from the Company through its ownership of the Company'sCompany’s Class B and Class D units. Holders of Clearway, Inc.'s’s Class A common stock and Class C common stock hold, in the aggregate, the remaining 45.07%45.09% of the voting interest in Clearway, Inc.'s’s stock. Each holder of Clearway, Inc.'s’s Class A or Class B common stock is entitled to one vote for each share held. Each holder of Clearway, Inc.'s’s Class C or Class D common stock is entitled to 1/100th of one vote for each share held. The holders of Clearway, Inc.'s’s outstanding shares of Class A and Class C common stock are entitled to dividends as declared. Clearway, Inc., through its holdings of the Company'sCompany’s Class A units and Class C units, owns a 57.65%57.88% economic interest in the Company. GIP, through CEG'sCEG’s holdings of the Company'sCompany’s Class B units and Class D units, owns a 42.35%42.12% economic interest in the Company.
CEG Master Services Agreements
The Company, along with Clearway, Inc. and Clearway Energy Operating LLC, entered into Master Services Agreements with CEG (the “CEG Master Services Agreements”), pursuant to which CEG and certain of its affiliates or third-party service providers provide certain services, including operational and administrative services, which include human resources, information systems, external affairs, accounting, procurement, and risk management services, to the Company and certain of its subsidiaries, and the Company and certain of its subsidiaries provide certain services, including accounting, internal audit, tax and treasury services, to CEG, in exchange for the payment of fees in respect of such services. For the year ended December 31, 2021,2022, the Company paid approximately $4,473,000$4,810,000 under the CEG Master Services Agreements. In addition, certain Thermal and Conventional segmentssegment projects reimbursed CEG approximately $896,000$228,000 during the year ended December 31, 20212022 for costs incurred by CEG on behalf of such entities.
Right of First Offer Agreements
CEG ROFO Agreement and Committed Investments
On August 31, 2018, the Company entered into a ROFO Agreement with CEG, or the CEG ROFO Agreement, and, solely for certain purposes thereof, GIP, pursuant to which CEG granted the Company and its subsidiaries a right of first offer on any proposed sale or transfer of certain assets owned by CEG. On August 1, 2019, the CEG ROFO Agreement was amended to grant the Company and its affiliates a right of first offer on any proposed sale, transfer or other disposition of certain assets of CEG, or the CEG ROFO Assets, until August 31, 2023, as listed in the table below. CEG is not obligated to sell the remaining CEG ROFO Assets to the Company and, if offered by CEG, the Company cannot be sure whether these assets will be offered on acceptable terms or that the Company will choose to consummate such acquisitions.
The assets listed below, all of which are included in a co-investment partnership with Hannon Armstrong Sustainable Infrastructure Capital, Inc.,partnerships, represent the Company'sCompany’s currently committed investments in projects with CEG and the CEG ROFO Assets:Assets:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Asset | | Technology | | Gross Capacity (MW) | | State | | COD | | Status |
Mililani IDaggett Solar 3 | | SolarSolar/Storage | | 39300 | | HICA | | 2H22 | | Committed |
Waiawa | | Solar | | 36 | | HI | | 2H221H23 | | Committed |
Daggett Solar 2 and 3 | | SolarSolar/Storage | | 482182 | | CA | | 2H22/1H232H23 | | Committed |
| Arica | | Solar/Storage | | 263 | | CA | | 2H23 | | Committed |
| Victory Pass | | Solar/Storage | | 200 | | CA | | 2H23 | | Committed |
| | | | | | | | | | |
Prior to engaging in any negotiation regarding any disposition, sale or other transfer of any of the remaining CEG ROFO Assets, CEG will deliver a written notice to the Company setting forth the material terms and conditions of the proposed transaction. During the 30‑day period after the delivery of such notice, the Company will negotiate with CEG in good faith to reach an agreement on the transaction. If the Company and CEG do not reach an agreement within such 30‑day period, CEG will be able to within the next 180 calendar days, to sell, transfer, dispose or recontract such CEG ROFO Asset to a third-party (or to agree in writing to undertake such transaction with a third-party on terms generally no less favorable to CEG than those offered pursuant to the written notice.
Under the CEG ROFO Agreement, CEG is not obligated to sell the remaining CEG ROFO Assets. In addition, any offer to sell under the CEG ROFO Agreement will be subject to an inherent conflict of interest because the same professionals within CEG’s organization that are involved in acquisitions that are suitable for the Company have responsibilities within CEG’s broader asset management business. Notwithstanding the significance of the services to be rendered by CEG or their designated affiliates on the Company'sCompany’s behalf or of the assets which the Company may elect to acquire from CEG in accordance with the terms of the CEG ROFO Agreement or otherwise, CEG does not owe fiduciary duties to the Company or its unit holders. Any material transaction with CEG (including the proposed acquisition of any CEG ROFO Asset) will be subject to the Company'sCompany’s related person transaction policy, which will require prior approval of such transaction by the Company'sCompany’s Corporate Governance, Conflicts and Nominating Committee.
The Company and CEG work collaboratively in considering new assets to be added under the CEG ROFO Agreement or to be acquired by the Company outside of the CEG ROFO Agreement.
Drop Drown Transactions and Partnerships with CEG
Daggett 3 Drop Down
On February 17, 2023, Daggett Solar Investment LLC, a subsidiary of the Company, acquired the Class A membership interests in Daggett Renewable Holdco LLC from Clearway Renew LLC, a subsidiary of CEG, for cash consideration of $21 million. Simultaneously, Daggett Renewable Holdco LLC acquired Daggett TargetCo LLC, the indirect owner of the Daggett 3 solar project, a 300 MW solar project with matching storage capacity that is currently under construction and located in San Bernardino, California. Daggett Renewable Holdco LLC is a partnership between the Company and a third-party investor. Daggett TargetCo LLC consolidates, as the direct owner of the primary beneficiary, a tax equity fund, Daggett TE Holdco LLC, which holds the Daggett 3 solar project. Daggett 3 has PPAs with investment-grade counterparties that have a 15-year weighted average contract duration that will commence when the project reaches commercial operations, which is expected to occur in the first half of 2023. The acquisition was funded with existing sources of liquidity.
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 with matching storage capacity located in Honolulu, Hawaii, from Clearway Renew LLC for cash consideration of $20 million. Lighthouse Renewable Holdco LLC is a partnership between the Company and a third-party investor. Waiawa BL Borrower Holdco LLC consolidates, as the direct owner of the primary beneficiary, a tax equity fund, Waiawa TE Holdco LLC, which directly holds the Waiawa solar project . Waiawa has a 20-year PPA with an investment-grade utility that commenced in January 2023.
In connection with the Waiawa Drop Down, the Company assumed non-recourse project-level debt, which included a construction loan, sponsor equity bridge loan and tax equity bridge loan. The $26 million 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 to the Company by CEG.
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 LLC, whereby Clearway Renew LLC 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. The assets within the portfolio sell power under PPAs with investment-grade counterparties that have a weighted average remaining contract duration of approximately 9 years.
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 with matching storage capacity located in Honolulu, Hawaii, from Clearway Renew LLC for cash consideration of $22 million. Lighthouse Renewable Holdco LLC is a partnership between the Company and a third-party investor. Mililani BL Borrower Holdco LLC consolidates, as the direct owner of the primary beneficiary, a tax equity fund, Mililani TE Holdco LLC, which directly holds the Mililani I solar project. Mililani I has a 20-year PPA with an investment-grade utility that commenced in July 2022.
In connection with the Mililani I Drop Down, the Company assumed non-recourse project-level debt, which included a construction loan, sponsor equity bridge loan and tax equity bridge loan. The $27 million 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 to the Company 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. The Company also paid an additional $3 million to Clearway Renew LLC for construction management fees.
Black Rock Drop Down
On December 29, 2021, the Company, through its indirect subsidiary, Lighthouse Renewable Holding Sub LLC, acquired the Class B membership interests in Black Rock Wind Holding LLC from Clearway Renew LLC, a subsidiary of CEG, for $60 million in cash consideration, $37 million of which wasLLC. During the year ended December 31, 2022, the Company paid on December 29, 2021 with the remainingan additional $23 million paid in February 2022 after all remaining turbines were operational. Lighthouse Renewable Holding Subto Clearway Renew LLC is a wholly-owned subsidiary of Lighthouse Renewable Holdco LLC, which is a partnership between the Company and a third-party investor. The Class A membership interests of Black Rock Wind Holding LLC were acquired by another third-party investor in 2020. Black Rock Wind Holding LLC, through its subsidiary, is the primary beneficiary and consolidates its interests in a tax equity fund, Black Rock TE Holdco LLC, that holds the Black Rock wind project, a 115 MW utility scale wind project located in Mineral County and Grant County, West Virginia. As of December 31, 2021, 70 MW of the 115 MW rated capacity were operational, representing fourteen of the twenty-three wind turbines, and the remaining 45 MW rated capacity became operational in January 2022. A majority of the project’s output is backed by contracts with investment-grade counterparties with a 15-year weighted average contract life.as final cash consideration.
Mesquite Sky Drop Down
On December 17, 2021, the Company, through its indirect subsidiary Lighthouse Renewable Holdco 2 LLC, acquired the Class B membership interests in Mesquite Sky Holding LLC from Clearway Renew LLC. During the year ended December 31, 2022, the Company paid an additional $7 million to Clearway Renew LLC a subsidiary of CEG, for $61 million inas final cash consideration. Lighthouse Renewable Holdco 2 LLC is a partnership between the Company and a third-party investor. The Class A membership interests of Mesquite Sky Holding LLC were acquired by another third-party investor in 2020. Mesquite Sky Holding LLC, through its subsidiary, is the primary beneficiary and consolidates its interests in a tax equity fund, Mesquite Sky TE Holdco LLC that holds the Mesquite Sky wind project, a 340 MW utility scale wind project located in Callahan County, Texas, which achieved commercial operations in December 2021. A majority of the project’s output is backed by contracts with investment-grade counterparties with a 12-year weighted average contract life.
Rattlesnake Drop Down
On January 12, 2021, the Company acquired 100% of CEG's equity interest and a third-party investor's minority interest in CWSP Rattlesnake Holding, LLC for $132 million in cash consideration. CWSP Rattlesnake Holding LLC indirectly consolidates the Rattlesnake wind project, a 160 MW wind facility with 144 MW deliverable capacity in Adams County, Washington. The project has a 20-year PPA with Avista Corporation, which began when the facility reached commercial operations in December 2020.
Pinnacle Repowering Partnership
On February 26, 2021, the Company entered into an amended agreement with CWSP Pinnacle Holding LLC, an indirect subsidiary of CEG, with respect to Pinnacle Repowering Partnership LLC in order to facilitate the repowering of the Pinnacle wind project, a 54 MW wind facility located in Mineral County, West Virginia. On March 10, 2021, the Company contributed its interest in the Pinnacle wind project to Pinnacle Repowering Partnership LLC concurrent with entering into a financing agreement. The Company owns 100% of the Class A membership interests in Pinnacle Repowering Partnership LLC, which is a VIE, and the Company consolidates its interest as the primary beneficiary and managing member. CWSP Pinnacle Holding LLC owns 100% of the Class B membership interests in Pinnacle Repowering Partnership LLC. On April 15, 2022, the Company acquired the Class B membership interests of Pinnacle Repowering Partnership LLC and is entitled to allocations of 15% of the cash distributions from the partnership. On March 10, 2021, CWSP Pinnacle Holding LLC contributed $27for cash consideration of $10 million in equipment toand the partnership, which was a transferCompany now owns and consolidates 100% of assets under common control and recorded at historical cost in property, plant and equipment, with a corresponding non-cash contributionthe membership interests in Pinnacle Repowering Partnership LLC's noncontrolling interests. Additionally, on March 10, 2021, the Pinnacle wind project acquired equipment from CEG for $21 million in cash consideration.LLC.
On December 15, 2021, in connection with the completion of the repowering of the project, a third-party tax equity investor acquired the Class A membership interests in Pinnacle Tax Equity Holdco LLC, which is a tax equity fund, and the holder of the Pinnacle wind project, for $48 million. The Company consolidates Pinnacle Tax Equity Holdco LLC, as primary beneficiary through its consolidated subsidiary Pinnacle Repowering Partnership LLC, who acts as managing member. In addition, upon completion of the repowering, the Company made a payment of $64 million, which was utilized along with the proceeds of the tax equity investment to repay the outstanding debt under the financing agreement referenced above.
The Company contributed $9 million into the partnershipAdditionally during the year ended December 31, 2021.2022, the Company paid $172,000 in project distributions.
Kawailoa Solar Partnership
On MayAugust 1, 2019,2022, the Company entered into a partnership withsold 100% of its Class A membership interests in Kawailoa Solar Partnership LLC, or the Kawailoa Partnership LLC, to Clearway Renew LLC a subsidiaryfor cash proceeds of CEG,$9 million. There were no project contributions from or distributions to own, finance, operate and maintain the Kawailoa Solar Partnership, which consists of the Kawailoa Solar Project, a 49 MW utility-scale solar generation project located in Oahu, Hawaii. The Company contributed $128,000 into the partnershipClearway Renew LLC during the year ended December 31, 2021.2022.
Oahu Solar Partnership
On March 8, 2019,August 1, 2022, the Company entered into a partnership withacquired the Class B membership interests of Zephyr Oahu Partnership LLC, or the Oahu Solar Partnership, from Clearway Renew LLC a subsidiaryfor cash consideration of CEG, to own, finance, operate$1 million and maintainthe Company now owns and consolidates 100% of the membership interests in the Oahu Solar projects, which consist of Lanikuhana and Waipio, 15 MW and 46 MW utility-scale solar generation projects, respectively, located in Oahu, Hawaii, which both reached COD in September 2019 and began to sell power to HECO pursuant to the long-term power purchase agreements. The Company contributed less than $120,000 into the partnership duringPartnership. During the year ended December 31, 2021.2022, Clearway Renew LLC contributed $1 million into the Oahu Partnership.
Operations and Maintenance Agreements
CEG provides operations and maintenance (“O&M”) and day‑to‑day operational support to the Company'sCompany’s utility scale solar and wind facilities in accordance with O&M agreements with the Company. Each of the counterparties to the O&M agreements is an affiliate of CEG. The O&M agreements for which the amount paid to CEG exceeded $120,000 during fiscalthe year 2021ended December 31, 2022 are described in the table below. Under these O&M agreements, the Company generally pays an annual or monthly fee, which may be subject to annual adjustment, plus any reimbursable expenses.
| | | | | | | | | | | | | | |
| Project | | Agreement Description | | Approximate Amount Paid to CEG |
| Solar | | | | |
| Agua Caliente | | O&M Agreement, dated December 22, 2017 | | $3,496,0004,439,000 | |
| | | | |
| Borrego | | O&M Agreement, dated August 1, 2012 | | $581,000473,000 | |
| Buckthorn Solar | | O&M Agreement, dated May 22, 2017 | | $2,881,0002,350,000 | |
| Chestnut Fund LLC | | O&M Agreement, dated FebruaryFeb 9, 2018 | | $769,000997,000 | |
| Clearway & EFS Distributed Solar LLC | | O&M Agreement, dated October 28, 2016 | | $209,000201,000 | |
| CS4 Fund LLC | | O&M Agreement, dated November 29, 2018 | | $919,000972,000 | |
| CVSR | | O&M Agreement, dated September 30, 2011 | | $3,666,0003,442,000 | |
DG-CSDG CS Holdco LLC | | O&M Agreement, dated November 2, 2020 | | $136,000360,000 | |
| DGPV Fund 1 LLC | | O&M Agreement, dated June 12, 2015 | | $243,000241,000 | |
| | | | | | | | | | | | | | |
Project | | Agreement Description | | Approximate Amount
Paid to CEG
|
| DGPV Fund 2 LLC | | O&M Agreement, dated September 4, 2015 | | $698,0001,038,000 | |
| DGPV Fund 4 LLC | | O&M Agreement, dated June 16, 2017 | | $1,126,000 | |
DGPV Holdco 3 LLC | | O&M Agreement, dated October 30, 2020 | | $134,0001,031,000 | |
| Golden Fields Solar III LLC | | O&M Agreement, dated February 25, 2020 | | $1,421,0001,643,000 | |
| Golden Puma Fund LLC | | O&M Agreement, dated March 30, 2017 | | $642,000694,000 | |
| Kansas South | | O&M Agreement, dated June 13, 2017 | | $713,000635,000 | |
Kawailoa Solar LLC | | O&M Agreement, dated December 14, 2017 | | $799,0001,565,000 | |
| Lanikuhana Solar LLC | | O&M Agreement, dated December 28, 2017 | | $390,000656,000 | |
| Mililani I | | O&M Agreement, dated May 28, 2021 | | $255,000 | |
| Solar Blythe | | O&M Agreement, dated November 1, 2017 | | $283,000267,000 | |
| Solar Blythe II | | O&M Agreement, dated March 1, 2017 | | $437,000670,000 | |
| Solar Community 1 LLC | | O&M Agreement, dated February 9, 2018 | | $214,000135,000 | |
| SPP Fund II | | O&M Agreement, dated October 31, 2017 | | $254,000206,000 | |
| SPP Fund III | | O&M Agreement, dated October 31, 2017 | | $214,000217,000 | |
| TA High Desert | | O&M Agreement, dated June 9, 2017 | | $520,000645,000 | |
| Utah Solar Portfolio | | O&M Agreement, dated June 13, 2022 | | $1,298,000 | |
| Utah Solar Holdings II LLC | | O&M Agreement, dated December 1, 2021 | | $178,000 | |
| Waipio PV LLC | | O&M Agreement, dated December 28, 2017 | | $762,0001,282,000 | |
| Wind | | | | |
| Alta Wind I | | O&M Agreement, dated December 12, 2016 | | $1,584,000 | |
| Alta Wind II | | O&M Agreement, dated December 12, 2016 | | $869,000 | |
| Alta Wind III | | O&M Agreement, dated December 12, 2016 | | $754,000 | |
| Alta Wind IV | | O&M Agreement, dated December 12, 2016 | | $558,000 | |
| Alta Wind V | | O&M Agreement, dated December 12, 2016 | | $854,000 | |
| Alta Wind X | | O&M Agreement, dated December 12, 2016 | | $1,678,0002,627,000 | |
| Alta Wind XI | | O&M Agreement, dated December 12, 2016 | | $1,674,0001,690,000 | |
Alta Wind IBlack Rock | | O&M Agreement, dated December 12, 201630, 2020 | | $1,500,000914,000 | |
Alta Wind IIBroken Bow | | O&M Agreement, dated December 12, 2016Nov 6, 2017 | | $671,000 | |
Alta Wind III | | O&M Agreement, dated December 12, 2016 | | $577,000 | |
Alta Wind IV | | O&M Agreement, dated December 12, 2016 | | $429,000 | |
Alta Wind V | | O&M Agreement, dated December 12, 2016 | | $627,000584,000 | |
| Buffalo Bear | | O&M Agreement, dated May 1, 2016 | | $313,000286,000 | |
| Cedro Hill | | O&M Agreement, dated Nov 11, 2015 | | $1,450,000 | |
| Crosswinds | | O&M Agreement, dated May 1, 2016 | | $671,000702,000 | |
| Elbow Creek | | O&M Agreement, dated October 31, 2018 | | $1,474,0001,491,000 | |
| Forward | | O&M Agreement, dated October 20, 2016 | | $482,000 | |
| Goat Wind | | O&M Agreement, dated February 18, 2008 | | $2,053,0002,682,000 | |
| Hardin | | O&M Agreement, dated May 1, 2016 | | $490,000452,000 | |
Langford Wind | | O&M Agreement, dated July 30, 2018 | | $2,593,0002,734,000 | |
| Laredo Ridge | | O&M Agreement, dated December 24, 2015 | | $1,375,0001,575,000 | |
| Lookout | | O&M Agreement, dated February 11, 2008 | | $945,0001,057,000 | |
| Mesquite Sky | | O&M Agreement, dated December 30, 2020 | | $1,602,000 | |
| Mesquite Star | | O&M Agreement, dated May 7, 2019 | | $4,822,0001,874,000 | |
| Mt. Storm | | O&M Agreement, dated April 23, 2021 | | $380,000783,000 | |
| Mountain Wind Power I & II | | O&M Agreement, dated September 17, 2016 | | $1,016,000 | |
| Ocotillo | | O&M Agreement, dated November 3, 2020 | | $934,000732,000 | |
| Odin | | O&M Agreement, dated September 16, 2016 | | $537,000474,000 | |
| Pinnacle | | O&M Agreement, dated December 1, 2016 | | $1,244,0001,335,000 | |
| Rattlesnake | | O&M Agreement, dated February 5, 2020 | | $1,421,0001,459,000 | |
| Sleeping Bear | | O&M Agreement, dated May 1, 2016 | | $1,891,0001,872,000 | |
| Spanish Fork | | O&M Agreement, dated September 16, 2016 | | $407,000364,000 | |
| South Trent | | Management O&M Agreement, dated October 1, 2015 | | $1,214,0001,732,000 | |
| Taloga | | O&M Agreement, dated July 1, 2016 | | $2,309,0002,679,000 | |
| Wildorado | | O&M Agreement, dated February 11, 2008 | | $1,945,0002,172,000 | |
Asset Management and Administrative Services Agreements
CEG provides day-to-day administrative support to certain of the Company'sCompany’s project-level entities in accordance with asset management and administrative services agreements (the “ASAs”). The ASAs for which the amount involved exceeded $120,000 during fiscalthe year 2020ended December 31, 2022 are described in the table below. Under these agreements, the Company generally pays an annual or monthly fee, which may be subject to annual adjustment, plus any reimbursable expenses.
| | | | | | | | | | | | | | |
| Project | | Agreement Description | | Approximate Amount Paid to CEG |
| Solar | | | | |
| Agua Caliente | | Asset Management Agreement, dated January 18, 2012 | | $968,000577,000 | |
| Alpine | | Asset Management Agreement, dated March 15, 2012 | | $150,000153,000 | |
| Buckthorn Solar | | Asset Management Agreement, dated May 22, 2017 | | $210,000171,000 | |
| Chestnut Fund LLC | | Asset Management Agreement, dated July 31, 2017 | | $219,000209,000 | |
| CS4 Fund LLC | | Asset Management Agreement, dated November 29, 2018 | | $316,000168,000 | |
| CVSR | | Asset Management Agreement, dated April 26, 2016 | | $222,000227,000 | |
| DG CS Holdco LLC | | Asset Management Agreement, dated November 2, 2020 | | $997,0002,067,000 | |
DGPV Fund 42 LLC | | Asset Management Agreement, dated June 28, 2016April 28,2017 | | $125,000156,000 | |
DGPV Holdco 3 LLC | | Asset Management Agreement, dated September 26, 2017 | | $287,000 | |
Golden Fields Solar III LLC | | Project Administration Agreement, dated February 25, 2020 | | $213,000 | |
Kawailoa Solar Holdings | | Asset Management Agreement, dated December 14, 2017 | | $157,000177,000 | |
| Oahu Solar | | Asset Management Agreement, dated December 28, 2017 | | $203,000213,000 | |
SPP Fund IIIRosamond Central | | Asset ManagementProject Administration Agreement, dated October 31, 2017February 25, 2020 | | $166,000156,000 | |
| SPP P-IV Master Lessee | | Asset Management Agreement, dated July 12, 2012 | | $187,000191,000 | |
| Utah Solar Holdings LLC | | Asset Management Agreement, dated December 1, 2021 | | $429,000 | |
| Utah Solar Holdings II LLC | | Asset Management Agreement, dated December 1, 2021 | | $429,000 | |
| Wind | | | | |
| Black Rock | | Project Administration Agreement, dated December 30, 2020 | | $275,000 | |
| Buffalo Bear | | Amended and Restated Services Agreement, dated September 15, 2011 | | $171,000175,000 | |
| Elbow Creek | | Project Administration Agreement, dated January 1, 2018 | | $255,000238,000 | |
| Forward | | Services Agreement, dated January 1, 2012 | | $197,000219,000 | |
| Langford | | Project Administration Agreement, dated April 24, 2020 | | $156,000157,000 | |
| Laredo Ridge | | Support Services Agreement, dated May 27, 2010 | | $187,000176,000 | |
| Lookout | | Services Agreement, dated January 1, 2012 | | $197,000219,000 | |
| Mesquite Sky | | Project Administration Agreement, dated December 30, 2020 | | $350,000 | |
| Mesquite Star | | Services Agreement, dated May 7, 2019 | | $497,000267,000 | |
MtMt. Storm | | Project Administration Agreement, dated April 23,23th, 2021 | | $151,000255,000 | |
| Pinnacle | | Amended and Restated Services Agreement, dated September 15, 2011 | | $211,000226,000 | |
| Rattlesnake | | Project Administration Agreement, dated February 5, 2020 | | $122,000125,000 | |
| Sleeping Bear | | Services Agreement, dated January 1, 2012 | | $197,000219,000 | |
| South Trent | | Project Administration Agreement, dated October 1, 2015 | | $235,000243,000 | |
| Spanish Fork | | Services Agreement, dated January 1, 2012 | | $197,000219,000 | |
| Taloga | | Services Agreement, dated November 20, 2012 | | $171,000174,000 | |
Viento Funding II, Inc.LLC | | Management and Administration Agreement, dated July 1, 2013 | | $269,000 | |
| Wildorado | | Project Administration Agreement, dated September 25, 2017 | | $255,000243,000 | |
Land Lease Agreements
The Company is party to various land lease agreements with CEG. The land lease agreements for which the amount involved exceeded $120,000 during the year ended December 31, 2022 are described in the table below. Under these agreements, the Company generally pays a quarterly or monthly fee, which may be subject to annual adjustment.
| | | | | | | | | | | | | | |
| Project | | Agreement Description | | Approximate Amount Paid to CEG |
| Solar | | | | |
| Mililani I | | Land Lease Agreement, dated November 19, 2020 | | $780,000 | |
Wind TE Holdco LLCOahu Solar | | ServicesLand Lease Agreement, dated November 3, 2014September 19, 2019 | | $1,118,000895,000 | |
| Rosamond Central | | Land Lease Agreement, dated November 18, 2020 | | $552,000 | |
Insurance Reimbursements
During 2021,2022, the Company paid approximately $1,310,000$1,210,000 for insurance premium reimbursements to CEG.
Fourth Amended and Restated Limited Liability Company Agreement of Clearway Energy LLC
The following is a description of the material terms of Clearway Energy LLC’s Fourth Amended and Restated Limited Liability Company Agreement (the “LLC Agreement”). For the year ended December 31, 2021,2022, Clearway Energy LLC made approximately $154,437,000$166,708,000 in distributions to Clearway, Inc. (the holder of Class A and $113,381,000Class C units) and $121,590,000 to CEG (the holder of Class B and Class D units). In addition to the quarterly distributions, the Company distributed an additional $11,100,000 to Clearway, Inc. and $8,111,000 to CEG during the third quarter of 2022 in order for Clearway, Inc. to make certain tax payments associated with the sale of the Thermal Business.
Governance
Clearway, Inc. serves as the sole managing member of the Company. As such, Clearway, Inc. and effectively Clearway, Inc.’s Board, control the business and affairs of the Company and are responsible for the management of the business.
Voting and Economic Rights of Members
The Company has four classes of Units: Class A units, Class B units, Class C units and Class D units. Class A units and Class C units may be issued only to Clearway, Inc. as the sole managing member, and Class B units and Class D units may be issued only to CEG and held by CEG or its permitted transferees. Units of each of the four classes have equivalent economic and other rights, except that upon issuance, each holder of a Class B unit will also be issued a share of Clearway, Inc.’s Class B common stock, and each holder of a Class D unit will also be issued a share of Clearway, Inc.’s Class D common stock. Each Class B unit is exchangeable for a share of Clearway, Inc.’s Class A common stock and each Class D unit is exchangeable for a share of Clearway, Inc.’s Class D common stock, in each case subject to equitable adjustments for stock splits, dividends and reclassifications in accordance with the terms of the Exchange Agreement (as described below).
Net profits and net losses and distributions by the Company are allocated and made to holders of units in accordance with the respective number of membership units of the Company held. Generally, the Company will make distributions to holders of units for the purpose of funding tax obligations in respect of income of the Company that is allocated to the members of the Company.
Clearway, Inc.’s Coordination with Clearway Energy LLC
Any time Clearway, Inc. issues a share of Class A common stock or a share of Class C common stock for cash, the net proceeds therefrom will promptly be transferred to the Company, and the Company will either:
• transfer a newly issued Class A unit of the Company to Clearway, Inc. in the case of the issuance of a share of Class A common stock, or a newly issued Class C unit of the Company to Clearway, Inc. in the case of the issuance of a share of Class C common stock; or
• use the net proceeds to purchase a Class B unit of the Company from CEG in the case of the issuance of a share of Class A common stock, which Class B unit will automatically convert into a Class A unit of the Company when transferred to Clearway, Inc., or a Class D unit of the Company from CEG in the case of the issuance of a share of Class C common stock, which Class D unit will automatically convert into a Class C unit of the Company when transferred to Clearway, Inc.
If Clearway, Inc. elects to redeem any shares of their Class A common stock or Class C common stock for cash, the Company will, immediately prior to such redemption, redeem an equal number of Class A units or Class C units, as applicable, held by Clearway, Inc. upon the same terms and for the same price, as the shares of Class A common stock so redeemed.
Exchange Agreement
Clearway, Inc. entered into an Amended and Restated Exchange Agreement with NRG (the “Exchange Agreement”), which was assigned to CEG upon the GIP Transaction. Under the Exchange Agreement, CEG (and certain permitted assignees and permitted transferees who acquire Class B units or Class D units of the Company) may from time to time cause us to exchange their Class B units for shares of Clearway, Inc.’s Class A common stock on a one‑for‑one basis, subject to adjustments for stock splits, stock dividends and reclassifications, or exchange their Class D units for shares of Clearway, Inc.’s Class C common stock on a one‑for‑one basis, subject to equitable adjustments for stock splits, stock dividends and reclassifications.
When CEG or its permitted transferee exchanges a Class B unit of the Company for a share of Clearway, Inc.’s Class A common stock, Clearway, Inc. will automatically redeem and cancel a corresponding share of their Class B common stock and the Class B unit will automatically convert into a Class A unit when issued to Clearway, Inc.; similarly, when CEG or its permitted transferee exchanges a Class D unit of the Company for a share of Clearway, Inc.’s Class C common stock, Clearway, Inc. will automatically redeem and cancel a corresponding share of their Class D common stock and the Class D unit will automatically convert into a Class C unit when issued to Clearway, Inc. As a result, when a holder exchanges its Class B units for shares of Clearway, Inc.’s Class A common stock, or its Class D units for shares of Clearway, Inc.’s Class C common stock, Clearway, Inc.’s interest in the Company will be correspondingly increased.
Indemnification of Officers
Clearway, Inc. has entered into indemnification agreements with each of its executive officers. The indemnification agreements provide the executive officers with contractual rights to indemnification, expense advancement and reimbursement to the fullest extent permitted under Delaware law.
Registration Rights Agreement
Clearway, Inc. entered into an Amended and Restated Registration Rights Agreement with NRG (the “Registration Rights Agreement”), which was assigned to CEG upon the GIP Transaction. Under the Registration Rights Agreement, CEG and its affiliates are entitled to demand registration rights, including the right to demand that a shelf registration statement be filed, and “piggyback” registration rights, for shares of Clearway, Inc.’s Class A common stock that are issuable upon exchange of Class B units of the Company that CEG owns and shares of Clearway, Inc.’s Class C common stock that are issuable upon exchange of the Class D units of the Company that CEG owns.
Procedures for Review, Approval and Ratification of Related Person Transactions; Conflicts of Interest
The Company does not have a separate policy regarding related party transactions, as all of its officers are subject to the written Related Person Policy of Clearway, Inc., which provides that the Corporate Governance, Conflicts and Nominating Committee of theClearway, Inc.’s Board of Directors will periodically review all related person transactions that are required to be disclosed under SEC rules and, when appropriate, initially authorize or ratify all such transactions.
The Related Person Policy operates in conjunction with Clearway, Inc.’s Code of Conduct and is applicable to all “Related Person Transactions”, which are all transactions, arrangements or relationships in which:
•the aggregate amount involved will or may be expected to exceed $50,000 in any calendar year;
•Clearway, Inc. is a participant; and
•any Related Person (as that term is defined below) has or will have a direct or indirect interest.
A “Related Person” is:
•any person who is, or at any time during the applicable period was, a director of the Company or a nominee for director or an executive officer;
•any person who is known to Clearway, Inc.toInc. to be the beneficial owner of more than 5% of any class of Clearway, Inc.’s voting stock;
•any immediate family member of any of the persons referenced in the preceding two bullets, which means any child, stepchild, parent, stepparent, spouse, sibling, mother‑in‑law, father‑in‑law, son‑in‑law, daughter‑in‑law, brother‑in‑law or sister‑in‑law of the director, nominee for director, executive officer or more than 5% beneficial owner of any class of Clearway, Inc.’s voting stock, and any person (other than a tenant or employee) sharing the household of such director, nominee for director, executive officer or more than 5% beneficial owner of any class of the Company’s voting stock; and
•any firm, corporation or other entity in which any of the foregoing persons is a partner or principal or in a similar position or in which such person has a 10% or greater beneficial ownership interest.
In determining whether to recommend the initial approval or ratification of a Related Person Transaction, the Corporate Governance, Conflicts and Nominating Committee considers all of the relevant facts and circumstances available, including (if applicable) but not limited to: (a) whether there is an appropriate business justification for the transaction; (b) the benefits that accrue to us as a result of the transaction; (c) the terms available to unrelated third parties entering into similar transactions; (d) the impact of the transaction on director independence (in the event the related person is a director, an immediate family member of a director or an entity in which a director or an immediate family member of a director is a partner, stockholder, member or executive officer); (e) the availability of other sources for comparable products or services; (f) whether it is a single transaction or a series of ongoing, related transactions; and (g) whether entering into the transaction would be consistent with the Related Person Transaction Policy.
If the aggregate amount involved is expected to be less than $500,000, the transaction may be approved or ratified by the Chair of the Corporate Governance, Conflicts and Nominating Committee.
As part of its review of each Related Person Transaction, the Corporate Governance, Conflicts and Nominating Committee will take into account, among other factors it deems appropriate, whether the transaction is on terms no less favorable than the terms generally available to an unaffiliated third‑party under the same or similar circumstances and the extent of the Related Person’s interest in the transaction. This Related Person Policy also provides that certain transactions, based on their nature and/or monetary amount, are deemed to be pre‑approved or ratified by the Corporate Governance, Conflicts and Nominating Committee and do not require separate approval or ratification.
Transactions involving ongoing relationships with a Related Person will be reviewed and assessed at least annually by the Corporate Governance, Conflicts and Nominating Committee to ensure that such Related Person Transactions remain appropriate and in compliance with the Committee’s guidelines.
The Committee’s activities with respect to the review and approval or ratification of all Related Person Transactions are reported periodically to the Board.Clearway, Inc.’s Board of Directors. Any transaction between us and any Related Person, including CEG, will be subject to the prior review and approval of the Company'sCompany’s Corporate Governance, Conflicts and Nominating Committee.
Item 14 — Principal Accounting Fees and Services
Audit and Nonaudit Fees
The following table presents fees for professional services rendered by Ernst & Young LLP, and KPMG LLP, the Company's principal independent registered public accounting firms, for the years ended December 31, 2021 and December 31, 2020, respectively:
| | | | | | | | | | | |
| Year Ended December 31, |
| 2021 (a) | | 2020 (b) |
| Audit Fees | $ | 4,424,556 | | | $ | 4,571,030 | |
| | | |
| Tax Fees | 1,605,408 | | | 261,340 | |
| All Other Fees | 6,560 | | | — | |
| Total | $ | 6,036,524 | | | $ | 4,832,370 | |
(a) Ernst & Young LLP was theCompany’s principal independent registered public accounting firm, for the yearyears ended December 31, 2021.
(b) KPMG LLP was the principal independent registered public accounting firm for the year ended2022 and December 31, 2020.2021:
| | | | | | | | | | | |
| Year Ended December 31, |
| 2022 | | 2021 |
| Audit Fees | $ | 4,484,400 | | | $ | 4,424,556 | |
| | | |
| Tax Fees | 1,560,400 | | | 1,605,408 | |
| All Other Fees | 6,560 | | | 6,560 | |
| Total | $ | 6,051,360 | | | $ | 6,036,524 | |
Audit Fees
TheFor 2022 and 2021, Ernst & Young LLP billed the Company was billed approximately $4,484,400 and $4,424,556, and $4,571,030 in 2021 and 2020 audit fees, respectively, coveringfor the integrated audit of the Company’s annual consolidated financial statements, internal control over financial reporting, and the review of the Company’s quarterly consolidated financial statements on Form 10-Q that are customary under the standards of the Public Company Accounting Oversight Board (United States), and in connection with statutory audits..
Audit-Related Fees
ThereFor 2022 and 2021, there were no audit-related fees billed to the Company in 2021 or 2020.by Ernst & Young LLP.
Tax Fees
TheFor 2022 and 2021, Ernst & Young LLP billed the Company was billed approximately $1,560,400 and $1,605,408, and $261,340 in 2021 and 2020 tax feesrespectively, relating mainly to compliance work.
All Other Fees
TheFor each of 2022 and 2021, Ernst & Young LLP billed the Company was billed approximately $6,560 in 2021 in other fees relating to online subscription fees. There were no other fees billed to the Company in 2020.
Policy on Audit Committee Pre-approval
The Audit Committee of Clearway Energy, Inc. is responsible for appointing, setting compensation for, and overseeing the work of the independent registered public accounting firm of the Company. The Audit Committee of Clearway Energy, Inc. has established a policy regarding pre-approval of all audit and permissible nonaudit services provided by the independent registered public accounting firm of the Company.
The Audit Committee of Clearway Energy, Inc. will annually review and pre-approve services that are expected to be provided by the independent registered public accounting firm. The term of the pre-approval will be 12 months from the date of the pre-approval, unless the Audit Committee of Clearway Energy, Inc. approves a shorter time period. The Audit Committee may periodically amend and/or supplement the pre-approved services based on subsequent determinations.
Unless the Audit Committee of Clearway Energy, Inc. has pre-approved Audit Services or a specified category of nonaudit services, any engagement to provide such services must be pre-approved by the Audit Committee of Clearway Energy, Inc. if it is to be provided by the independent registered public accounting firm. The Audit Committee of Clearway Energy, Inc. must also pre-approve any proposed services exceeding the pre-approved budgeted fee levels for a specified type of service.
The Audit Committee of Clearway Energy, Inc. has authorized its Chair to pre-approve services in amounts up to $100,000 per engagement. Engagements exceeding $100,000 must be approved by the full Audit Committee of Clearway Energy, Inc. Engagements pre-approved by the Chair are reported to the Audit Committee of Clearway Energy, Inc. at its next scheduled meeting. The Audit Committee of Clearway Energy, Inc. approved all of the audit-related fees, tax fees and all other fees disclosed above.
PART IV
Item 15 — Exhibits, Financial Statement Schedules
(a)(1) Financial Statements
The following consolidated financial statements of Clearway Energy LLC and related notes thereto, together with the Report of Independent Registered Public Accounting Firm of Ernst & Young LLP (PCAOB ID: 42) and Report of Independent Registered Public Accounting Firm of KPMG LLP (PCAOB ID: 185) thereon, are included herein:
Consolidated Statements of OperationsIncome — Years ended December 31, 2022, 2021 2020 and 20192020
Consolidated Statements of Comprehensive Income (Loss) — Years ended December 31, 2022, 2021 2020 and 20192020
Consolidated Balance Sheets — As of December 31, 20212022 and 20202021
Consolidated Statements of Cash Flows — Years ended December 31, 2022, 2021 2020 and 20192020
Consolidated Statements of Members'Members’ Equity — Years ended December 31, 2022, 2021 2020 and 20192020
Notes to Consolidated Financial Statements
(a)(2) Financial Statement Schedules
The following schedules of Clearway Energy, Inc. are filed as part of Item 15 of this report and should be read in conjunction with the Consolidated Financial Statements:
Schedule I — Clearway Energy LLC (Parent) Condensed Financial Statements for the years ended December 31, 2022, 2021 2020 and 2019,2020, are included in Clearway Energy LLC'sLLC’s Annual Report on Form 10-K pursuant to the requirements of Rule 5-04(c) of Regulation S-X
All other schedules for which provision is made in the applicable accounting regulation of the Securities and Exchange Commission are not required under the related instructions or are inapplicable, and therefore, have been omitted
(a)(3) Exhibits: See Exhibit Index submitted as a separate section of this report
(b) Exhibits
See Exhibit Index submitted as a separate section of this report
(c) Not applicable
Report of Independent Registered Public Accounting Firm
To the Members
of Clearway Energy LLC:
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheetsheets of Clearway Energy LLC (the Company) as of December 31, 2022 and 2021, the related consolidated statements of operations,income, comprehensive income, (loss), members’ equity and cash flows for each of the year thentwo years in the period ended December 31, 2022, and the related notes and financial statement schedule listed in the Index at Item 15(a)(2) (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company at December 31, 2022 and 2021 and the results of its operations and its cash flows for each of the year thentwo years in the period ended December 31, 2022, in conformity with U.S. generally accepted accounting principles.
Basis for Opinion
These financial statements are the responsibility of the Company’sCompany's management. Our responsibility is to express an opinion on the Company’s financial statements based on our audit.audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’sCompany's internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
| | | | | |
| Allocation of earnings to noncontrolling interests in tax equity arrangements |
| |
| Description of the Matter | As described in Note 5 to the consolidated financial statements, during 2021 third-party2022, tax equity investors purchased noncontrolling interests in Rattlesnake TE Holdco LLC (Rattlesnake), Black Rock TE Holdco LLC, Mesquite SkyMililani TE Holdco LLC and Pinnacle Repowering Tax EquityWaiawa TE Holdco LLC (the “new tax equity arrangements”). Each tax equity investor received Class A membership interests in the respective entity. The Company utilizes the output of a hypothetical liquidation at book value (HLBV) model to determine the earnings allocated to the tax equity noncontrolling interest holders as the contractual agreements between the parties represent substantive profit-sharing arrangements.
Auditing the allocation of earnings using the HLBV method to the new tax equity arrangements was complex due to the judgments required at the inception of the arrangement to evaluate whether the HLBV model appropriately reflects the unique substantive profit-sharing terms and features within each arrangement. A greater extent of audit effort and specialized skill and knowledge was required with respect to evaluating the appropriateness of the tax capital account balances used in the HLBV model for compliance with the provisions of the Internal Revenue Code, as well as compliance with the contractual provisions in each agreement. |
| |
| | | | | |
| How We Addressed the Matter in Our Audit | We obtained an understanding, evaluated the design and tested the operating effectiveness of the control over the Company'sCompany’s process for establishing the HLBV model for the new tax equity arrangements. For example, we tested a control over management’s review of the substantive profit-sharing terms and features within each arrangement and evaluatingevaluated whether they are properly reflected in each HLBV model.
To test the allocation of earnings to noncontrolling interest holders in the new tax equity arrangements, we read the related agreements to understand the business purpose and the substantive profit-sharing provisions. We evaluated each HLBV model for consistency with the contractual provisions in the related agreements and tested the initial recognition of the noncontrolling interest balance by agreeing capital contributions to supporting documentation. We involved tax subject matter professionals to assist in evaluating the calculation of the tax capital accounts used in each HLBV model for compliance with the provisions of the Internal Revenue Code, as well as compliance with the contractual provisions in the agreements. agreements. Additionally, we tested the periodyear end noncontrolling interest balances for the new tax equity arrangements by agreeing contributions and distributions to supporting documentation and recalculating the allocation of earnings using each HLBV model. |
| |
| Fair value of Level 3 energy related commodity contracts |
| |
| Description of the Matter | As described in Note 6 to the consolidated financial statements, as of December 31, 2021,2022, the aggregate fair value of energy related commodity contracts classified as Level 3 derivative instruments was $179$353 million. The Company'sCompany’s determination of the fair value of long-term physically-settled power commodity contracts executed in illiquid markets are considered Level 3 fair value measurements as they contain significant unobservable inputs, including forward market energy pricing curves. The Company uses a discounted cash flow valuation technique to determine the fair value of its energy related commodity contracts.
Auditing the fair value measurement of energy related commodity contracts classified as Level 3 financial instruments was complex due to the judgmental nature of the forward market energy pricing curve assumptions used as an input into the valuation models. |
| | | | | |
| |
| How We Addressed the Matter in Our Audit | We obtained an understanding, evaluated the design and tested the operating effectiveness of controls over the Company'sCompany’s processes for reviewing the key assumptions in estimating Level 3 fair values. For example, we tested controls over management’s review of the specific forward market energy pricing curves used as an input into the valuation models.
To test the fair value of Level 3 energy related commodity contracts, our audit procedures included, among others, evaluating the valuation methodologies used by the Company and testing significant inputs, estimates and the mathematical accuracy of the calculations. In certain instances, with the assistance of our valuation specialists, we independently determined the significant assumptions, calculated the resultant fair values and compared them to the Company'sCompany’s estimates. We obtained forward market energy prices from independent sources, including pricing service providers and counterparty fair values, and evaluated the Company'sCompany’s assumptions related to their forward curves and confirmed key inputs with counterparties. We also performed sensitivity analyses using independent sources of market data to evaluate the significance of the change in fair value of Level 3 energy related commodity contracts that would result from changes in underlying assumptions. |
/s/ Ernst & Young LLP
We have served as the Company’s auditor since 2021.
Philadelphia, Pennsylvania
February 25, 202223, 2023
Report of Independent Registered Public Accounting Firm
To the Members
Clearway Energy LLC:
Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated balance sheetstatements of income, comprehensive income, members’ equity, and cash flows of Clearway Energy, LLC and subsidiaries (the Company) as of December 31, 2020,for the related consolidated statements of operations, comprehensive income (loss), members’ equity, and cash flows for each of the years in the two‑year period ended December 31, 2020, and the related notes and financial statement schedule “Schedule I-Condensed Financial Information of Registrant” (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial positionresults of operations of the Company as of December 31, 2020, and the results of its operations and its cash flows for each of the years in the two‑year period ended December 31, 2020, in conformity with U.S. generally accepted accounting principles.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.audit. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our auditsaudit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our auditsaudit included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our auditsaudit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provideaudit provides a reasonable basis for our opinion.
/s/ KPMG LLP
We served as the Company’s auditor from 2012 to 2021.
/s/ KPMG LLP
Philadelphia, Pennsylvania
March 1, 2021
CLEARWAY ENERGY LLC
CONSOLIDATED STATEMENTS OF OPERATIONSINCOME | | | Year ended December 31, | | Year ended December 31, |
| (In millions) | (In millions) | 2021 | | 2020 | | 2019 | (In millions) | 2022 | | 2021 | | 2020 |
| Operating Revenues | Operating Revenues | | | | | | Operating Revenues | | | | | |
| Total operating revenues | Total operating revenues | $ | 1,286 | | | $ | 1,199 | | | $ | 1,032 | | Total operating revenues | $ | 1,190 | | | $ | 1,286 | | | $ | 1,199 | |
| Operating Costs and Expenses | Operating Costs and Expenses | | | | | | Operating Costs and Expenses | | | | | |
| Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 451 | | | 366 | | | 337 | | Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 435 | | | 451 | | | 366 | |
| Depreciation, amortization and accretion | Depreciation, amortization and accretion | 509 | | | 428 | | | 401 | | Depreciation, amortization and accretion | 512 | | | 509 | | | 428 | |
| Impairment losses | Impairment losses | 6 | | | 24 | | | 33 | | Impairment losses | 16 | | | 6 | | | 24 | |
| General and administrative | General and administrative | 38 | | | 33 | | | 27 | | General and administrative | 38 | | | 38 | | | 33 | |
| Transaction and integration costs | Transaction and integration costs | 7 | | | 9 | | | 3 | | Transaction and integration costs | 7 | | | 7 | | | 9 | |
| Development costs | Development costs | 6 | | | 5 | | | 5 | | Development costs | 2 | | | 6 | | | 5 | |
| Total operating costs and expenses | Total operating costs and expenses | 1,017 | | | 865 | | | 806 | | Total operating costs and expenses | 1,010 | | | 1,017 | | | 865 | |
| Gain on sale of business | | Gain on sale of business | 1,292 | | | — | | | — | |
| Operating Income | Operating Income | 269 | | | 334 | | | 226 | | Operating Income | 1,472 | | | 269 | | | 334 | |
| Other Income (Expense) | Other Income (Expense) | | | | | | Other Income (Expense) | | | | | |
| Equity in earnings of unconsolidated affiliates | Equity in earnings of unconsolidated affiliates | 32 | | | 7 | | | 83 | | Equity in earnings of unconsolidated affiliates | 29 | | | 32 | | | 7 | |
| Impairment loss on investment | Impairment loss on investment | — | | | (8) | | | — | | Impairment loss on investment | — | | | — | | | (8) | |
| Gain on sale of unconsolidated affiliate | Gain on sale of unconsolidated affiliate | — | | | 49 | | | — | | Gain on sale of unconsolidated affiliate | — | | | — | | | 49 | |
| Other income, net | Other income, net | 3 | | | 4 | | | 9 | | Other income, net | 17 | | | 3 | | | 4 | |
| Loss on debt extinguishment | Loss on debt extinguishment | (53) | | | (24) | | | (16) | | Loss on debt extinguishment | (2) | | | (53) | | | (24) | |
| Interest expense | Interest expense | (312) | | | (414) | | | (403) | | Interest expense | (232) | | | (312) | | | (414) | |
| Total other expense, net | Total other expense, net | (330) | | | (386) | | | (327) | | Total other expense, net | (188) | | | (330) | | | (386) | |
| Loss Before Income Taxes | (61) | | | (52) | | | (101) | | |
| Income (Loss) Before Income Taxes | | Income (Loss) Before Income Taxes | 1,284 | | | (61) | | | (52) | |
| Income tax expense | Income tax expense | 2 | | | — | | | — | | Income tax expense | 2 | | | 2 | | | — | |
| Net Loss | (63) | | | (52) | | | (101) | | |
| Less: Net loss attributable to noncontrolling interests | (173) | | | (113) | | | (71) | | |
| Net Income (Loss) Attributable to Clearway Energy LLC | $ | 110 | | | $ | 61 | | | $ | (30) | | |
| Net Income (Loss) | | Net Income (Loss) | 1,282 | | | (63) | | | (52) | |
| Less: Net loss attributable to noncontrolling interests and redeemable interests | | Less: Net loss attributable to noncontrolling interests and redeemable interests | (106) | | | (173) | | | (113) | |
| Net Income Attributable to Clearway Energy LLC | | Net Income Attributable to Clearway Energy LLC | $ | 1,388 | | | $ | 110 | | | $ | 61 | |
See accompanying notes to consolidated financial statements.
CLEARWAY ENERGY LLC
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
| | | | | | | | | | | | | | | | | |
| Year ended December 31, |
| 2021 | | 2020 | | 2019 |
| (In millions) | | | | | |
| Net Loss | $ | (63) | | | $ | (52) | | | $ | (101) | |
| Other Comprehensive Income | | | | | |
| Unrealized gain on derivatives | 22 | | 2 | | 8 |
| Other comprehensive income | 22 | | | 2 | | | 8 | |
| Comprehensive Loss | (41) | | | (50) | | | (93) | |
| Less: Comprehensive loss attributable to noncontrolling interests | (171) | | | (115) | | | (70) | |
| Comprehensive Income (Loss) Attributable to Clearway Energy LLC | $ | 130 | | | $ | 65 | | | (23) | |
| | | | | | | | | | | | | | | | | |
| Year ended December 31, |
| 2022 | | 2021 | | 2020 |
| (In millions) | | | | | |
| Net Income (Loss) | $ | 1,282 | | | $ | (63) | | | $ | (52) | |
| Other Comprehensive Income | | | | | |
| Unrealized gain on derivatives and changes in accumulated OCI/OCL | 33 | | 22 | | 2 |
| Other comprehensive income | 33 | | | 22 | | | 2 | |
| Comprehensive Income (Loss) | 1,315 | | | (41) | | | (50) | |
| Less: Comprehensive loss attributable to noncontrolling interests and redeemable interests | (100) | | | (171) | | | (115) | |
| Comprehensive Income Attributable to Clearway Energy LLC | $ | 1,415 | | | $ | 130 | | | 65 | |
See accompanying notes to consolidated financial statements.
CLEARWAY ENERGY LLC
CONSOLIDATED BALANCE SHEETS | | | | | | | | | | | |
| December 31, 2021 | | December 31, 2020 |
| ASSETS | (In millions) |
| Current Assets | | | |
| Cash and cash equivalents | $ | 179 | | | $ | 268 | |
| Restricted cash | 475 | | | 197 | |
| Accounts receivable — trade | 144 | | | 143 | |
| | | |
| Inventory | 37 | | | 42 | |
| Current assets held-for-sale | 631 | | | — | |
| | | |
| | | |
| | | |
| Prepayments and other current assets | 65 | | | 58 | |
| Total current assets | 1,531 | | | 708 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Property, plant and equipment, net | 7,650 | | | 7,217 | |
| Other Assets | | | |
| Equity investments in affiliates | 381 | | | 741 | |
| Intangible assets for power purchase agreements, net | 2,419 | | | 1,230 | |
| Other intangible assets, net | 80 | | | 140 | |
| Derivative instruments | 6 | | | 1 | |
| Right-of-use assets, net | 550 | | | 337 | |
| Other non-current assets | 101 | | | 114 | |
| Total other assets | 3,537 | | | 2,563 | |
| Total Assets | $ | 12,718 | | | $ | 10,488 | |
| LIABILITIES AND MEMBERS' EQUITY | | | |
| Current Liabilities | | | |
| Current portion of long-term debt — external | $ | 772 | | | $ | 384 | |
| Current portion of long-term debt — affiliate | 1 | | | 1 | |
| Accounts payable — trade | 74 | | | 72 | |
| Accounts payable — affiliates | 110 | | | 20 | |
| Derivative instruments | 46 | | | 38 | |
| Accrued interest expense | 54 | | | 44 | |
| Current liabilities held-for-sale | 494 | | | — | |
| Accrued expenses and other current liabilities | 84 | | | 79 | |
| Total current liabilities | 1,635 | | | 638 | |
| Other Liabilities | | | |
| Long-term debt — external | 6,939 | | | 6,585 | |
| | | |
| | | |
| | | |
| Deferred income taxes | 2 | | | — | |
| Derivative instruments | 196 | | | 135 | |
| Long-term lease liabilities | 561 | | | 345 | |
| Other non-current liabilities | 168 | | | 173 | |
| Total other liabilities | 7,866 | | | 7,238 | |
| Total Liabilities | 9,501 | | | 7,876 | |
| Commitments and Contingencies | — | | | — | |
| Members' Equity | | | |
| Contributed capital | 1,495 | | | 1,723 | |
| Retained earnings (accumulated deficit) | 43 | | | (50) | |
| Accumulated other comprehensive loss | (13) | | | (33) | |
| Noncontrolling interest | 1,692 | | | 972 | |
| Total Members' Equity | 3,217 | | | 2,612 | |
| Total Liabilities and Members’ Equity | $ | 12,718 | | | $ | 10,488 | |
| | | | | | | | | | | |
| December 31, 2022 | | December 31, 2021 |
| ASSETS | (In millions) |
| Current Assets | | | |
| Cash and cash equivalents | $ | 657 | | | $ | 179 | |
| Restricted cash | 339 | | | 475 | |
| Accounts receivable — trade | 153 | | | 144 | |
| | | |
| Inventory | 47 | | | 37 | |
| Current assets held-for-sale | — | | | 631 | |
| Derivative instruments | 26 | | | — | |
| | | |
| | | |
| Prepayments and other current assets | 54 | | | 65 | |
| Total current assets | 1,276 | | | 1,531 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Property, plant and equipment, net | 7,421 | | | 7,650 | |
| Other Assets | | | |
| Equity investments in affiliates | 364 | | | 381 | |
| Intangible assets for power purchase agreements, net | 2,488 | | | 2,419 | |
| Other intangible assets, net | 77 | | | 80 | |
| Derivative instruments | 63 | | | 6 | |
| Right-of-use assets, net | 527 | | | 550 | |
| Other non-current assets | 96 | | | 101 | |
| Total other assets | 3,615 | | | 3,537 | |
| Total Assets | $ | 12,312 | | | $ | 12,718 | |
| LIABILITIES AND MEMBERS’ EQUITY | | | |
| Current Liabilities | | | |
| Current portion of long-term debt — external | $ | 322 | | | $ | 772 | |
| Current portion of long-term debt — affiliate | 2 | | | 1 | |
| Accounts payable — trade | 55 | | | 74 | |
| Accounts payable — affiliates | 24 | | | 110 | |
| Derivative instruments | 50 | | | 46 | |
| Accrued interest expense | 54 | | | 54 | |
| Current liabilities held-for-sale | — | | | 494 | |
| Accrued expenses and other current liabilities | 95 | | | 84 | |
| Total current liabilities | 602 | | | 1,635 | |
| Other Liabilities | | | |
| Long-term debt — external | 6,491 | | | 6,939 | |
| | | |
| | | |
| | | |
| Deferred income taxes | 4 | | | 2 | |
| Derivative instruments | 303 | | | 196 | |
| Long-term lease liabilities | 548 | | | 561 | |
| Other non-current liabilities | 197 | | | 168 | |
| Total other liabilities | 7,543 | | | 7,866 | |
| Total Liabilities | 8,145 | | | 9,501 | |
| Redeemable noncontrolling interest in subsidiaries | 7 | | | — | |
| Commitments and Contingencies | | | |
| Members’ Equity | | | |
| Contributed capital | 1,308 | | | 1,495 | |
| Retained earnings | 1,240 | | | 43 | |
| Accumulated other comprehensive income (loss) | 21 | | | (13) | |
| Noncontrolling interest | 1,591 | | | 1,692 | |
| Total Members’ Equity | 4,160 | | | 3,217 | |
| Total Liabilities and Members’ Equity | $ | 12,312 | | | $ | 12,718 | |
See accompanying notes to consolidated financial statements.
CLEARWAY ENERGY LLC
CONSOLIDATED STATEMENTS OF CASH FLOWS | | | Year ended December 31, | | Year ended December 31, |
| (In millions) | 2021 | | 2020 | | 2019 | |
| | | 2022 | | 2021 | | 2020 |
| Cash Flows from Operating Activities | Cash Flows from Operating Activities | | | | | | Cash Flows from Operating Activities | (In millions) |
| Net loss | $ | (63) | | | $ | (52) | | | $ | (101) | | |
| Adjustments to reconcile net loss to net cash provided by operating activities: | | | |
| Net income (loss) | | Net income (loss) | $ | 1,282 | | | $ | (63) | | | $ | (52) | |
| Adjustments to reconcile net income (loss) to net cash provided by operating activities: | | Adjustments to reconcile net income (loss) to net cash provided by operating activities: | | |
| Equity in earnings of unconsolidated affiliates | Equity in earnings of unconsolidated affiliates | (32) | | | (7) | | | (83) | | Equity in earnings of unconsolidated affiliates | (29) | | | (32) | | | (7) | |
| Distributions from unconsolidated affiliates | Distributions from unconsolidated affiliates | 38 | | | 61 | | | 34 | | Distributions from unconsolidated affiliates | 37 | | | 38 | | | 61 | |
| Depreciation, amortization and accretion | Depreciation, amortization and accretion | 509 | | | 428 | | | 401 | | Depreciation, amortization and accretion | 512 | | | 509 | | | 428 | |
| Amortization of financing costs and debt discounts | Amortization of financing costs and debt discounts | 14 | | | 15 | | | 15 | | Amortization of financing costs and debt discounts | 14 | | | 14 | | | 15 | |
| Amortization of intangibles and out-of-market contracts | 146 | | | 90 | | | 71 | | |
| Amortization of intangibles | | Amortization of intangibles | 172 | | | 146 | | | 90 | |
| Loss on debt extinguishment | Loss on debt extinguishment | 53 | | | 24 | | | 16 | | Loss on debt extinguishment | 2 | | | 53 | | | 24 | |
| Reduction in carrying amount of right-of-use assets | Reduction in carrying amount of right-of-use assets | 11 | | | 4 | | | 7 | | Reduction in carrying amount of right-of-use assets | 14 | | | 11 | | | 4 | |
| Gain on sale of unconsolidated affiliate | Gain on sale of unconsolidated affiliate | — | | | (49) | | | — | | Gain on sale of unconsolidated affiliate | — | | | — | | | (49) | |
| Gain on sale of business | | Gain on sale of business | (1,292) | | | — | | | — | |
| Impairment losses | Impairment losses | 6 | | | 32 | | | 33 | | Impairment losses | 16 | | | 6 | | | 32 | |
| Change in deferred income taxes | Change in deferred income taxes | 2 | | | — | | | — | | Change in deferred income taxes | 2 | | | 2 | | | — | |
| Changes in derivative instruments | 28 | | | 44 | | | 85 | | |
| Changes in derivative instruments and amortization of accumulated OCI/OCL | | Changes in derivative instruments and amortization of accumulated OCI/OCL | 69 | | | 28 | | | 44 | |
| Loss on disposal of asset components | Loss on disposal of asset components | — | | | 3 | | | 9 | | Loss on disposal of asset components | — | | | — | | | 3 | |
| Cash provided (used) in changes in other working capital | Cash provided (used) in changes in other working capital | | Cash provided (used) in changes in other working capital | |
| Changes in prepaid and accrued liabilities for tolling agreements | Changes in prepaid and accrued liabilities for tolling agreements | 5 | | | (1) | | | 1 | | Changes in prepaid and accrued liabilities for tolling agreements | 10 | | | 5 | | | (1) | |
| Changes in other working capital | Changes in other working capital | (16) | | | (47) | | | (19) | | Changes in other working capital | (12) | | | (16) | | | (47) | |
| Net Cash Provided by Operating Activities | Net Cash Provided by Operating Activities | 701 | | | 545 | | | 469 | | Net Cash Provided by Operating Activities | 797 | | | 701 | | | 545 | |
| Cash Flows from Investing Activities | Cash Flows from Investing Activities | | | | | | Cash Flows from Investing Activities | | | | | |
| Acquisitions, net of cash acquired | Acquisitions, net of cash acquired | (533) | | | — | | | (100) | | Acquisitions, net of cash acquired | — | | | (533) | | | — | |
| Partnership interest acquisition | — | | | — | | | (29) | | |
| Acquisition of Drop Down Assets, net of cash acquired | Acquisition of Drop Down Assets, net of cash acquired | (229) | | | (122) | | | (161) | | Acquisition of Drop Down Assets, net of cash acquired | (71) | | | (229) | | | (122) | |
| Acquisition of Capistrano Wind Portfolio, net of cash acquired | | Acquisition of Capistrano Wind Portfolio, net of cash acquired | (223) | | | — | | | — | |
| Capital expenditures | Capital expenditures | (151) | | | (124) | | | (228) | | Capital expenditures | (112) | | | (151) | | | (124) | |
| Asset purchase from affiliate | Asset purchase from affiliate | (21) | | | — | | | — | | Asset purchase from affiliate | — | | | (21) | | | — | |
| Buyout of Wind TE Holdco non-controlling interest | — | | | — | | | (19) | | |
| | Return of investment from unconsolidated affiliates | Return of investment from unconsolidated affiliates | 47 | | | 79 | | | 56 | | Return of investment from unconsolidated affiliates | 13 | | | 47 | | | 79 | |
| Investments in unconsolidated affiliates | Investments in unconsolidated affiliates | — | | | (11) | | | (13) | | Investments in unconsolidated affiliates | — | | | — | | | (11) | |
| Proceeds from sale of assets | Proceeds from sale of assets | — | | | 90 | | | 20 | | Proceeds from sale of assets | — | | | — | | | 90 | |
| Proceeds from sale of business | | Proceeds from sale of business | 1,457 | | | — | | | — | |
| Consolidation of DGPV Holdco 3 LLC | Consolidation of DGPV Holdco 3 LLC | — | | | 17 | | | — | | Consolidation of DGPV Holdco 3 LLC | — | | | — | | | 17 | |
| | Other | Other | 22 | | | 9 | | | 6 | | Other | 1 | | | 22 | | | 9 | |
| Net Cash Used in Investing Activities | (865) | | | (62) | | | (468) | | |
| Net Cash Provided by (Used in) Investing Activities | | Net Cash Provided by (Used in) Investing Activities | 1,065 | | | (865) | | | (62) | |
| Cash Flows from Financing Activities | Cash Flows from Financing Activities | | | | | | Cash Flows from Financing Activities | | | | | |
| Contributions from noncontrolling interests, net of distributions | Contributions from noncontrolling interests, net of distributions | 680 | | | 247 | | | 174 | | Contributions from noncontrolling interests, net of distributions | 47 | | | 680 | | | 247 | |
| Contributions from CEG, net of distributions | Contributions from CEG, net of distributions | 287 | | | — | | | — | | Contributions from CEG, net of distributions | 13 | | | 287 | | | — | |
| Buyout of Repowering Partnership II LLC noncontrolling interest | Buyout of Repowering Partnership II LLC noncontrolling interest | — | | | (70) | | | — | | Buyout of Repowering Partnership II LLC noncontrolling interest | — | | | — | | | (70) | |
| Proceeds from the issuance of class C units | Proceeds from the issuance of class C units | — | | | 62 | | | 100 | | Proceeds from the issuance of class C units | — | | | — | | | 62 | |
| Payments of distributions | Payments of distributions | (268) | | | (211) | | | (155) | | Payments of distributions | (289) | | | (268) | | | (211) | |
| Distributions to CEG of escrowed amounts | | Distributions to CEG of escrowed amounts | (64) | | | — | | | — | |
| Tax-related distributions | | Tax-related distributions | (19) | | | — | | | — | |
| Proceeds from the revolving credit facility | Proceeds from the revolving credit facility | 622 | | | 265 | | | 152 | | Proceeds from the revolving credit facility | 80 | | | 622 | | | 265 | |
| Payments for the revolving credit facility | Payments for the revolving credit facility | (377) | | | (265) | | | (152) | | Payments for the revolving credit facility | (325) | | | (377) | | | (265) | |
| Proceeds from issuance of long-term debt — external | Proceeds from issuance of long-term debt — external | 1,728 | | | 1,084 | | | 1,215 | | Proceeds from issuance of long-term debt — external | 244 | | | 1,728 | | | 1,084 | |
| Proceeds from issuance of long-term debt — affiliate | Proceeds from issuance of long-term debt — affiliate | 2 | | | 3 | | | — | | Proceeds from issuance of long-term debt — affiliate | 4 | | | 2 | | | 3 | |
| Payments of debt issuance costs | Payments of debt issuance costs | (20) | | | (20) | | | (25) | | Payments of debt issuance costs | (4) | | | (20) | | | (20) | |
| Payments for long-term debt — external | Payments for long-term debt — external | (2,292) | | | (1,482) | | | (1,264) | | Payments for long-term debt — external | (1,198) | | | (2,292) | | | (1,482) | |
| Payments for long-term debt — affiliate | Payments for long-term debt — affiliate | (2) | | | (45) | | | (215) | | Payments for long-term debt — affiliate | (3) | | | (2) | | | (45) | |
| Other | Other | 7 | | | — | | | — | | Other | (6) | | | 7 | | | — | |
| Net Cash Provided by (Used in) Financing Activities | 367 | | | (432) | | | (170) | | |
| Net Cash (Used in) Provided by Financing Activities | | Net Cash (Used in) Provided by Financing Activities | (1,520) | | | 367 | | | (432) | |
| Reclassification of Cash to Assets Held-for-Sale | Reclassification of Cash to Assets Held-for-Sale | (14) | | | — | | | — | | Reclassification of Cash to Assets Held-for-Sale | — | | | (14) | | | — | |
| Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash | 189 | | | 51 | | | (169) | | |
| Net Increase in Cash, Cash Equivalents and Restricted Cash | | Net Increase in Cash, Cash Equivalents and Restricted Cash | 342 | | | 189 | | | 51 | |
| Cash, Cash Equivalents and Restricted Cash at Beginning of Period | Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 465 | | | 414 | | | 583 | | Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 654 | | | 465 | | | 414 | |
| Cash, Cash Equivalents and Restricted Cash at End of Period | Cash, Cash Equivalents and Restricted Cash at End of Period | $ | 654 | | | $ | 465 | | | $ | 414 | | Cash, Cash Equivalents and Restricted Cash at End of Period | $ | 996 | | | $ | 654 | | | $ | 465 | |
| | Supplemental Disclosures | | |
| Supplemental Disclosures: | | Supplemental Disclosures: | |
| Interest paid, net of amount capitalized | Interest paid, net of amount capitalized | $ | (337) | | | $ | (325) | | | $ | (307) | | Interest paid, net of amount capitalized | $ | (317) | | | $ | (337) | | | $ | (325) | |
| Non-cash investing and financing activities: | Non-cash investing and financing activities: | | Non-cash investing and financing activities: | |
| Reductions to fixed assets for accrued capital expenditures | (32) | | | (18) | | | (2) | | |
| Non-cash contributions from CEG, net of distributions | 31 | | | 7 | | | 35 | | |
| | Non-cash (distributions to), contributions from CEG | | Non-cash (distributions to), contributions from CEG | (4) | | | 31 | | | 7 | |
See accompanying notes to consolidated financial statements.
CLEARWAY ENERGY LLC
CONSOLIDATED STATEMENTS OF MEMBERS'MEMBERS’ EQUITY
| | (In millions) | (In millions) | | Contributed Capital | | Retained Earnings (Accumulated Deficit) | | Accumulated
Other
Comprehensive
Loss | | Noncontrolling Interest | | Total
Members' Equity | (In millions) | | Contributed Capital | | Retained Earnings (Accumulated Deficit) | | Accumulated
Other
Comprehensive
(Loss) Income | | Noncontrolling Interest | | Total
Members’ Equity |
| Balances at December 31, 2018 | | $ | 1,940 | | | $ | 86 | | | $ | (44) | | | $ | 200 | | | $ | 2,182 | | |
| Net loss | | — | | | (30) | | | — | | | (71) | | | (101) | | |
| Unrealized gain on derivatives | | — | | | — | | | 7 | | | — | | | 7 | | |
| Buyout of Wind TE Holdco non-controlling interest | | (9) | | | — | | | — | | | (10) | | | (19) | | |
| Contributions from CEG net of distributions, non-cash | | 7 | | | 4 | | | — | | | 24 | | | 35 | | |
| Cumulative effect from change in accounting principle | | — | | | (3) | | | — | | | — | | | (3) | | |
| Distributions paid to CEG on Class B and Class D units | | (38) | | | (30) | | | — | | | — | | | (68) | | |
| Distributions paid to Clearway Energy, Inc., cash | | (65) | | | (22) | | | — | | | — | | | (87) | | |
| Distributions paid to Clearway Energy, Inc., non-cash | | (13) | | | — | | | — | | | — | | | (13) | | |
| Contributions to tax equity non-controlling interests, net of distributions, cash | | (5) | | | — | | | — | | | 248 | | | 243 | | |
| Distributions to CEG, net of contributions, cash | | — | | | — | | | — | | | (68) | | | (68) | | |
| Proceeds from the issuance of Class C Common Stock | | 100 | | | — | | | — | | | — | | | 100 | | |
| Carlsbad Drop Down | | (35) | | | — | | | — | | | — | | | (35) | | |
| Balances at December 31, 2019 | Balances at December 31, 2019 | | $ | 1,882 | | | $ | 5 | | | $ | (37) | | | $ | 323 | | | $ | 2,173 | | Balances at December 31, 2019 | | $ | 1,882 | | | $ | 5 | | | $ | (37) | | | $ | 323 | | | $ | 2,173 | |
| Net income (loss) | Net income (loss) | | — | | | 61 | | | — | | | (113) | | | (52) | | Net income (loss) | | — | | | 61 | | | — | | | (113) | | | (52) | |
| Unrealized gain on derivatives | | — | | | — | | | 4 | | | (2) | | | 2 | | |
| Unrealized gain on derivatives and changes in accumulated OCL | | Unrealized gain on derivatives and changes in accumulated OCL | | — | | | — | | | 4 | | | (2) | | | 2 | |
| Contributions from CEG, non-cash | Contributions from CEG, non-cash | | 8 | | | — | | | — | | | (1) | | | 7 | | Contributions from CEG, non-cash | | 8 | | | — | | | — | | | (1) | | | 7 | |
| Contributions from CEG, cash | Contributions from CEG, cash | | — | | | — | | | — | | | 6 | | | 6 | | Contributions from CEG, cash | | — | | | — | | | — | | | 6 | | | 6 | |
| Distributions to noncontrolling interests, non-cash | Distributions to noncontrolling interests, non-cash | | — | | | — | | | — | | | (3) | | | (3) | | Distributions to noncontrolling interests, non-cash | | — | | | — | | | — | | | (3) | | | (3) | |
| Contributions from noncontrolling interests, net of distributions, cash | Contributions from noncontrolling interests, net of distributions, cash | | — | | | — | | | — | | | 361 | | | 361 | | Contributions from noncontrolling interests, net of distributions, cash | | — | | | — | | | — | | | 361 | | | 361 | |
| DGPV Drop Down and Consolidation | DGPV Drop Down and Consolidation | | (33) | | | — | | | — | | | 13 | | | (20) | | DGPV Drop Down and Consolidation | | (33) | | | — | | | — | | | 13 | | | (20) | |
| Mesquite Star Drop Down and Consolidation | Mesquite Star Drop Down and Consolidation | | 15 | | | — | | | — | | | 346 | | | 361 | | Mesquite Star Drop Down and Consolidation | | 15 | | | — | | | — | | | 346 | | | 361 | |
| Langford Drop Down | Langford Drop Down | | (44) | | | — | | | — | | | — | | | (44) | | Langford Drop Down | | (44) | | | — | | | — | | | — | | | (44) | |
| Rosamond Central Drop Down | Rosamond Central Drop Down | | 3 | | | — | | | — | | | 52 | | | 55 | | Rosamond Central Drop Down | | 3 | | | — | | | — | | | 52 | | | 55 | |
| Lighthouse Partnership Yield Protection Agreement | Lighthouse Partnership Yield Protection Agreement | | (15) | | | — | | | — | | | — | | | (15) | | Lighthouse Partnership Yield Protection Agreement | | (15) | | | — | | | — | | | — | | | (15) | |
| Buyout of Repowering Partnership II LLC non-controlling interest | Buyout of Repowering Partnership II LLC non-controlling interest | | (60) | | | — | | | — | | | (10) | | | (70) | | Buyout of Repowering Partnership II LLC non-controlling interest | | (60) | | | — | | | — | | | (10) | | | (70) | |
| Net proceeds from the sales of units, Clearway Energy, Inc. | Net proceeds from the sales of units, Clearway Energy, Inc. | | 62 | | | — | | | — | | | — | | | 62 | | Net proceeds from the sales of units, Clearway Energy, Inc. | | 62 | | | — | | | — | | | — | | | 62 | |
| Distributions paid to CEG on Class B and Class D units | | (36) | | | (54) | | | — | | | — | | | (90) | | |
| Distributions paid to Clearway Energy, Inc. | | (59) | | | (62) | | | — | | | — | | | (121) | | |
| Distributions paid to CEG on Class B and Class D unit holders | | Distributions paid to CEG on Class B and Class D unit holders | | (36) | | | (54) | | | — | | | — | | | (90) | |
| Distributions paid to Clearway, Inc. | | Distributions paid to Clearway, Inc. | | (59) | | | (62) | | | — | | | — | | | (121) | |
| Balances at December 31, 2020 | Balances at December 31, 2020 | | $ | 1,723 | | | $ | (50) | | | $ | (33) | | | $ | 972 | | | $ | 2,612 | | Balances at December 31, 2020 | | 1,723 | | | (50) | | | (33) | | | 972 | | | 2,612 | |
| Net income (loss) | Net income (loss) | | — | | | 110 | | | — | | | (176) | | | (66) | | Net income (loss) | | — | | | 110 | | | — | | | (176) | | | (66) | |
| Unrealized gain on derivatives | | — | | | — | | | 20 | | | 2 | | | 22 | | |
| Unrealized gain on derivatives and changes in accumulated OCL | | Unrealized gain on derivatives and changes in accumulated OCL | | — | | | — | | | 20 | | | 2 | | | 22 | |
| Contributions from CEG, net of distributions, non-cash | Contributions from CEG, net of distributions, non-cash | | 2 | | | — | | | — | | | 29 | | | 31 | | Contributions from CEG, net of distributions, non-cash | | 2 | | | — | | | — | | | 29 | | | 31 | |
| Contributions from CEG, net of distributions, cash | Contributions from CEG, net of distributions, cash | | 287 | | | — | | | — | | | 9 | | | 296 | | Contributions from CEG, net of distributions, cash | | 287 | | | — | | | — | | | 9 | | | 296 | |
| Contributions from noncontrolling interests, net of distributions, cash | Contributions from noncontrolling interests, net of distributions, cash | | — | | | — | | | — | | | 676 | | | 676 | | Contributions from noncontrolling interests, net of distributions, cash | | — | | | — | | | — | | | 676 | | | 676 | |
| Distributions paid to CEG on Class B and Class D units | | (96) | | | (17) | | | — | | | — | | | (113) | | |
| Distributions paid to Clearway Energy, Inc. | | (155) | | | — | | | — | | | — | | | (155) | | |
| Distributions paid to CEG on Class B and Class D unit holders | | Distributions paid to CEG on Class B and Class D unit holders | | (96) | | | (17) | | | — | | | — | | | (113) | |
| Distributions paid to Clearway, Inc. | | Distributions paid to Clearway, Inc. | | (155) | | | — | | | — | | | — | | | (155) | |
| Lighthouse Partnership Yield Protection Agreement Amendment | Lighthouse Partnership Yield Protection Agreement Amendment | | 15 | | | — | | | — | | | — | | | 15 | | Lighthouse Partnership Yield Protection Agreement Amendment | | 15 | | | — | | | — | | | — | | | 15 | |
| Agua Acquisition | | — | | | — | | | — | | | 273 | | | 273 | | |
| Agua Caliente Acquisition | | Agua Caliente Acquisition | | — | | | — | | | — | | | 273 | | | 273 | |
| Rattlesnake Drop Down | Rattlesnake Drop Down | | (117) | | | — | | | — | | | — | | | (117) | | Rattlesnake Drop Down | | (117) | | | — | | | — | | | — | | | (117) | |
| Mesquite Sky Drop Down | Mesquite Sky Drop Down | | (42) | | | — | | | — | | | (78) | | | (120) | | Mesquite Sky Drop Down | | (42) | | | — | | | — | | | (78) | | | (120) | |
| Black Rock Drop Down | Black Rock Drop Down | | (122) | | | — | | | — | | | (15) | | | (137) | | Black Rock Drop Down | | (122) | | | — | | | — | | | (15) | | | (137) | |
| Balances at December 31, 2021 | Balances at December 31, 2021 | | $ | 1,495 | | | $ | 43 | | | $ | (13) | | | $ | 1,692 | | | $ | 3,217 | | Balances at December 31, 2021 | | 1,495 | | | 43 | | | (13) | | | 1,692 | | | 3,217 | |
| Net income (loss) | | Net income (loss) | | — | | | 1,388 | | | — | | | (117) | | | 1,271 | |
| Unrealized gain on derivatives and changes in accumulated OCI | | Unrealized gain on derivatives and changes in accumulated OCI | | — | | | — | | | 27 | | | 6 | | | 33 | |
| (Distributions to) contributions from CEG, non-cash | | (Distributions to) contributions from CEG, non-cash | | (18) | | | — | | | — | | | 14 | | | (4) | |
| Contributions from (distributions to) CEG, cash | | Contributions from (distributions to) CEG, cash | | 48 | | | — | | | — | | | (32) | | | 16 | |
| | (Distributions to) contributions from noncontrolling interests, cash | | (Distributions to) contributions from noncontrolling interests, cash | | — | | | — | | | — | | | 51 | | | 51 | |
| Mesquite Sky Drop Down | | Mesquite Sky Drop Down | | (7) | | | — | | | — | | | (1) | | | (8) | |
| Black Rock Drop Down | | Black Rock Drop Down | | 2 | | | — | | | — | | | (1) | | | 1 | |
| Mililani I Drop Down | | Mililani I Drop Down | | (41) | | | — | | | — | | | 11 | | | (30) | |
| Waiawa Drop Down | | Waiawa Drop Down | | (38) | | | — | | | — | | | 17 | | | (21) | |
| Capistrano Wind Portfolio Acquisition | | Capistrano Wind Portfolio Acquisition | | 4 | | | — | | | 7 | | | — | | | 11 | |
| Kawailoa Sale to Clearway Renew LLC | | Kawailoa Sale to Clearway Renew LLC | | (20) | | | — | | | — | | | (49) | | | (69) | |
| Tax-related distributions | | Tax-related distributions | | — | | | (19) | | | — | | | — | | | (19) | |
| Distributions paid to Clearway, Inc. | | Distributions paid to Clearway, Inc. | | (82) | | | (85) | | | — | | | — | | | (167) | |
| Distributions paid to CEG Class B and Class D unit holders | | Distributions paid to CEG Class B and Class D unit holders | | (35) | | | (87) | | | — | | | — | | | (122) | |
| Balances at December 31, 2022 | | Balances at December 31, 2022 | | $ | 1,308 | | | $ | 1,240 | | | $ | 21 | | | $ | 1,591 | | | $ | 4,160 | |
See accompanying notes to consolidated financial statements.
CLEARWAY ENERGY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 — Nature of Business
Clearway Energy LLC, together with its consolidated subsidiaries, or the Company, is an energy infrastructure investor with a focus on investments in clean energy and owner of modern, sustainable and long-term contracted assets across North America. The Company is sponsored by GIP and TotalEnergies through GIP'sthe portfolio company, Clearway Energy Group LLC, or CEG, which became equally owned by GIP and TotalEnergies as of September 12, 2022, when TotalEnergies acquired, through its investment in an intermediate holding company, 50% of GIP’s interest in CEG. 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.
The Company is one of the largest renewable energy owners in the U.S. with over 5,0005,500 net MW of installed wind and solar generation projects. The Company'sCompany’s over 9,0008,000 net MW of assets also includes approximately 2,500 net MW of environmentally-sound, highly efficient natural gas-fired generation facilities as well as the Thermal Business.facilities. Through this environmentally-sound, diversified and primarily contracted portfolio, the Company endeavors to increase distributions to its unit holders. The majoritySubstantially all of the Company's generation assetsCompany’s revenues are underderived from long-term contractual arrangements for the output or capacity from these assets.
On October 22, 2021, Clearway Energy Operating LLC entered into a binding agreement to sellMay 1, 2022, the Company completed the sale of 100% of its interests in the Thermal Business to KKR, or the Thermal Disposition.KKR. For further details of the Thermal Disposition, refer to Note 3, Acquisitions and Dispositions.
Clearway Energy, Inc., or Clearway, Inc., consolidates the results of the Company through its controlling interest, with CEG'sCEG’s interest shown as non-controlling interestcontributed capital in the Company’s consolidated financial statements. The holders of Clearway, Inc.'s’s outstanding shares of Class A and Class C common stock are entitled to dividends as declared. CEG receives its distributions from the Company through its ownership of the Company'sCompany’s Class B and Class D units. From time to time, CEG may also hold shares of Clearway Inc’s Class A and/or Class C common stock.
As of December 31, 2021,2022, Clearway, Inc. owned 57.65%57.88% of the economic interests of the Company, with CEG owning 42.35%42.12% of the economic interests of the Company. For further discussion, see Note 11, Members'Members’ Equity.
The following tablediagram below represents thea summarized structure of the Company as of December 31, 2021:2022:
Note 2 — Summary of Significant Accounting Policies
Basis of Presentation and Principles of Consolidation
The Company'sCompany’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'sCompany’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 a majority of the voting interests of an entity. However, a controlling financial interest may also exist through arrangements that do not involve controlling voting interests. As such, the Company applies the guidance of ASC 810, Consolidations, or ASC 810, to determine when an entity that is insufficiently capitalized or not controlled through its voting interests, referred to as a 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 $146$121 million and $149$146 million as of December 31, 20212022 and 2020,2021, 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:
| | | | Year ended December 31, | | December 31, |
| | | 2021 | | 2020 | | | 2022 | | 2021 | |
| | | (In millions) | | (In millions) |
| Cash and cash equivalents | Cash and cash equivalents | $ | 179 | | | $ | 268 | | | Cash and cash equivalents | $ | 657 | | | $ | 179 | | |
| Restricted cash | Restricted cash | 475 | | | 197 | | | Restricted cash | 339 | | | 475 | | |
| Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows | Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows | $ | 654 | | | $ | 465 | | | Cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows | $ | 996 | | | $ | 654 | | |
Restricted cash consists primarily of funds held to satisfy the requirements of certain debt agreements and funds held within the Company'sCompany’s projects that are restricted in their use. As of December 31, 2021,2022, these restricted funds were comprised of $246$109 million designated to fund operating expenses, approximately $34$55 million designated for current debt service payments and $131$105 million restricted for reserves including debt service, performance obligations and other reserves as well as capital expenditures. The remaining $64$70 million is held in distributions reserve accounts.
In 2020, the members of the partnerships holding the Oahu Solar and Kawailoa Solar projects submitted applications to the state of Hawaii for refundable tax credits based on the cost of construction of the projects. In April 2021, the members of the partnerships contributed their respective portions of the tax credits in the amount of $49$27 million to the Oahu Solar and $22 million to the Kawailoa Solar project companies, which waswere recorded to restricted cash on the Company'sCompany’s consolidated balance sheet with an offsetting adjustment to noncontrolling interests. In accordance with the projects'projects’ related agreements, the cash is held in a restricted account and utilized to offset invoiced amounts under the projects'projects’ PPAs. On August 1, 2022, the Company sold its Class A membership interests in the Kawailoa Partnership, which consolidates the Kawailoa Solar project, to Clearway Renew LLC, as further described in Note 3, Acquisitions and Dispositions, resulting in the removal of $7 million that remained in restricted cash at the time of sale. As of December 31, 2021, $202022, $26 million of the $49$27 million previously contributed to the Oahu Solar projects has been utilized to offset invoiced amounts under the projects'projects’ PPAs.
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 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, 20212022 and 2020.2021.
Inventory
Inventory consists principally of spare parts and fuel oil. Spare parts inventory 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. Fuel oil inventory is valued at the lower of weighted average cost or market. The Company removes fuel inventories as they are used in the production of steam, chilled water or electricity. Spare parts inventoryInventory is removed when used for repairs, maintenance or capital projects.
Property, Plant and Equipment
Property, plant and equipment are stated at cost;cost, however impairment adjustments are recorded whenever events or changes in circumstances indicate that their carrying valuesamounts may not be recoverable. Significant additions or improvements extending asset lives are capitalized as incurred, while repairs and maintenance that do not improve or extend the life of the respective asset are charged to expense as incurred. Depreciation is computed using the straight-line method over the estimated useful lives. Certain assets and their related accumulated depreciation amounts are adjusted for asset retirements and disposals with the resulting gain or loss included in cost of operations in the consolidated statements of operations.income. For further discussion of the Company'sCompany’s property, plant and equipment refer to Note 4, Property, Plant and Equipment.
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.
Development costs include project development costs, which are expensed in the preliminary stages of a project and capitalized when the project is deemed to be commercially viable. Commercial viability is determined by one or a series of actions including, among others, Board of Director approval pursuant to a formal project plan that subjects the Company to significant future obligations that can only be discharged by the use of a Company asset. When a project is available for operations, capitalized interest and capitalized project development costs are reclassified to property, plant and equipment and depreciated on a straight-line basis over the estimated useful life of the project'sproject’s related assets. Capitalized costs are charged to expense if a project is abandoned or management otherwise determines the costs to be unrecoverable.
Asset Impairments
Long-lived assets that are held and used are reviewed for impairment whenever events or changes in circumstances indicate their carrying valuesamounts 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 value.amount. An impairment charge is measured as the excess of an asset'sasset’s carrying amount over its fair value with the difference recorded in operating costs and expenses in the consolidated statements of operations.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'sCompany’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, customer relationships, customer contracts, 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'sCompany’s intangible assets, refer to Note 8, Intangible Assets.
Income Taxes
The Company is classified as a partnership for federal and state income tax purposes. Therefore, federal and most state income taxes are assessed at the partner level. The franchise tax imposed by the state of Texas, however, is being assessed at the level of certain project subsidiaries of the Company, and therefore reflected as an income tax expense of the Company.
For the year ended December 31, 2022, the Company recorded a deferred tax expense of $2 million and associated deferred tax liability of $4 million with respect to future years. At December 31, 2021, the Company recorded a deferred tax expense and associated deferred tax liability of $2 million with respect to future years. At December 31, 2021, the Company had no current tax liability.
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'sCompany’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.
Thermal Revenues
Steam and chilled water revenue is recognized as the Company transfers 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 recognize 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 is satisfied over time and revenue is recognized based on the invoiced amount. The Thermal Business subsidiaries collect and remit state and local taxes associated with sales to their customers, as required by governmental authorities. These taxes are presented on a net basis in the consolidated statements of operations.income.
As contracts for steam and chilled water are long-term contracts,On May 1, 2022, the Company has performance obligations under these contracts that have not yet been satisfied. These performance obligations have transaction prices that are both fixed and variable, and that vary based oncompleted the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the Company cannot accurately estimate the amountsale of 100% of its unsatisfied performance obligations as it will vary based on customer usage, which will depend on factors such as weather and customer activity.
On October 22, 2021, Clearway Energy Operating LLC entered into a binding agreement to sellinterests in the Thermal Businessbusiness to KKR. For further details of the Thermal Disposition refer to Note 3, Acquisitions and DispositionsDispositions.
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. 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. 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 capital lease.
Certain of these leasesPPAs have no minimum lease payments and all of the lease revenue derived fromunder these leasesPPAs 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, 2022, 2021 and 2020 and 2019 was $850 million, $741 million $589 million and $537$589 million, respectively. See Note 15, Leases, for additional information related to the Company'sCompany’s PPAs accounted for as leases.
Renewable Energy Credits, or RECs
As stated above, renewableRenewable 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 for the year ended December 31, 2021,2022, along with the reportable segment for each category:
| | | Year ended December 31, 2021 | | Year ended December 31, 2022 |
| (In millions) | (In millions) | Conventional Generation | | Renewables | | Thermal | | | Total | (In millions) | Conventional Generation | | Renewables | | Thermal | | | Total |
Energy revenue (a) | Energy revenue (a) | $ | 9 | | | $ | 784 | | | $ | 122 | | | | $ | 915 | | Energy revenue (a) | $ | 6 | | | $ | 956 | | | $ | 48 | | | | $ | 1,010 | |
Capacity revenue (a) | Capacity revenue (a) | 455 | | | 2 | | | 53 | | | | 510 | | Capacity revenue (a) | 435 | | | 2 | | | 18 | | | | 455 | |
| Other revenues | Other revenues | — | | | 60 | | | 32 | | | | 92 | | Other revenues | — | | | 71 | | | 11 | | | | 82 | |
| Contract amortization | Contract amortization | (23) | | | (118) | | | (3) | | | | (144) | | Contract amortization | (24) | | | (151) | | | — | | | | (175) | |
| Mark-to-market for economic hedges | Mark-to-market for economic hedges | — | | | (87) | | | — | | | | (87) | | Mark-to-market for economic hedges | — | | | (182) | | | — | | | | (182) | |
| Total operating revenue | 441 | | | 641 | | | 204 | | | | 1,286 | | |
| Total operating revenues | | Total operating revenues | 417 | | | 696 | | | 77 | | | | 1,190 | |
| Less: Contract amortization | | Less: Contract amortization | 24 | | | 151 | | | — | | | | 175 | |
| Less: Mark-to-market for economic hedges | | Less: Mark-to-market for economic hedges | — | | | 182 | | | — | | | | 182 | |
| Less: Lease revenue | Less: Lease revenue | (464) | | | (716) | | | (2) | | | | (1,182) | | Less: Lease revenue | (441) | | | (809) | | | (1) | | | | (1,251) | |
| Less: Contract amortization | 23 | | | 118 | | | 3 | | | | 144 | | |
| | Total revenue from contracts with customers | Total revenue from contracts with customers | $ | — | | | $ | 43 | | | $ | 205 | | | | $ | 248 | | Total revenue from contracts with customers | $ | — | | | $ | 220 | | | $ | 76 | | | | $ | 296 | |
|
(a) See Note 15, Leases, for the amounts of energy and capacity revenue that relate to leases and are accounted for under ASC 842.
The following tables represent the Company’s disaggregation of revenue from contracts with customers for the year ended December 31, 2020,2021, along with the reportable segment for each category:
| | | Year ended December 31, 2020 | | Year ended December 31, 2021 |
| (In millions) | (In millions) | Conventional Generation | | Renewables | | Thermal | | | Total | (In millions) | Conventional Generation | | Renewables | | Thermal | | | Total |
Energy revenue (a) | Energy revenue (a) | $ | 10 | | | $ | 609 | | | $ | 101 | | | | $ | 720 | | Energy revenue (a) | $ | 9 | | | $ | 784 | | | $ | 122 | | | | $ | 915 | |
Capacity revenue (a) | Capacity revenue (a) | 451 | | | — | | | 63 | | | | 514 | | Capacity revenue (a) | 455 | | | 2 | | | 53 | | | | 510 | |
| Other revenues | Other revenues | — | | | 21 | | | 32 | | | | 53 | | Other revenues | — | | | 60 | | | 32 | | | | 92 | |
| Contract amortization | Contract amortization | (24) | | | (61) | | | (3) | | | | (88) | | Contract amortization | (23) | | | (118) | | | (3) | | | | (144) | |
| | Total operating revenue | 437 | | | 569 | | | 193 | | | | 1,199 | | |
| Mark-to-market for economic hedges | | Mark-to-market for economic hedges | — | | | (87) | | | — | | | | (87) | |
| Total operating revenues | | Total operating revenues | 441 | | | 641 | | | 204 | | | | 1,286 | |
| Less: Contract amortization | | Less: Contract amortization | 23 | | | 118 | | | 3 | | | | 144 | |
| Less: Mark-to-market for economic hedges | | Less: Mark-to-market for economic hedges | — | | | 87 | | | — | | | | 87 | |
| Less: Lease revenue | Less: Lease revenue | (461) | | | (554) | | | (2) | | | | (1,017) | | Less: Lease revenue | (464) | | | (716) | | | (2) | | | | (1,182) | |
| Less: Contract amortization | 24 | | | 61 | | | 3 | | | | 88 | | |
| Total revenue from contracts with customers | Total revenue from contracts with customers | $ | — | | | $ | 76 | | | $ | 194 | | | | $ | 270 | | Total revenue from contracts with customers | $ | — | | | $ | 130 | | | $ | 205 | | | | $ | 335 | |
(a) See Note 15, Leases, for the amounts of energy and capacity revenue that relate to leases and are accounted for under ASC 842.
The following tables represent the Company’s disaggregation of revenue from contracts with customers for the year ended December 31, 2019,2020, along with the reportable segment for each category:
| | | Year ended December 31, 2019 | | Year ended December 31, 2020 | |
| (In millions) | (In millions) | Conventional Generation | | Renewables | | Thermal | | | Total | (In millions) | Conventional Generation | | Renewables | | Thermal | | | Total | |
Energy revenue (a) | Energy revenue (a) | $ | 5 | | | $ | 545 | | | $ | 120 | | | | $ | 670 | | Energy revenue (a) | $ | 10 | | | $ | 609 | | | $ | 101 | | | | $ | 720 | | |
Capacity revenue (a) | Capacity revenue (a) | 348 | | | — | | | 54 | | | | 402 | | Capacity revenue (a) | 451 | | | — | | | 63 | | | | 514 | | |
| Other revenues | Other revenues | — | | | 10 | | | 30 | | | | 40 | | Other revenues | — | | | 21 | | | 32 | | | | 53 | | |
| Contract amortization | Contract amortization | (7) | | | (61) | | | (3) | | | | (71) | | Contract amortization | (24) | | | (61) | | | (3) | | | | (88) | | |
| Mark-to-market for economic hedges | — | | | (9) | | | — | | | | (9) | | |
| Total operating revenue | 346 | | | 485 | | | 201 | | | | 1,032 | | |
| | Total operating revenues | | Total operating revenues | 437 | | | 569 | | | 193 | | | | 1,199 | | |
| Less: Contract amortization | | Less: Contract amortization | 24 | | | 61 | | | 3 | | | | 88 | |
| | Less: Lease revenue | Less: Lease revenue | (353) | | | (509) | | | (2) | | | | (864) | | Less: Lease revenue | (461) | | | (554) | | | (2) | | | | (1,017) | | |
| Less: Contract amortization | 7 | | | 61 | | | 3 | | | | 71 | | |
| Total revenue from contracts with customers | Total revenue from contracts with customers | $ | — | | | $ | 37 | | | $ | 202 | | | | $ | 239 | | Total revenue from contracts with customers | $ | — | | | $ | 76 | | | $ | 194 | | | | $ | 270 | | |
(a) See Note 15, 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 net amount of contract assets and liabilities included on the Company’s consolidated balance sheets as of December 31, 20212022 and December 31, 2020:2021: | | (In millions) | (In millions) | | December 31, 2021 | | December 31, 2020 | (In millions) | | December 31, 2022 | | December 31, 2021 |
| Accounts receivable, net - Contracts with customers | Accounts receivable, net - Contracts with customers | | $ | 44 | | | $ | 57 | | Accounts receivable, net - Contracts with customers | | $ | 37 | | | $ | 44 | |
| Accounts receivable, net - Leases | Accounts receivable, net - Leases | | 100 | | | 86 | | Accounts receivable, net - Leases | | 116 | | | 100 | |
| Total accounts receivable, net | Total accounts receivable, net | | $ | 144 | | | $ | 143 | | Total accounts receivable, net | | $ | 153 | | | $ | 144 | |
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 either:
•Recognized in earnings as an offset to the changes in the fair value of the related hedged assets, liabilities and firm commitments; or
•Deferred and recorded as a component of accumulated OCI until the hedged transactions occur and are recognized in earnings.
The Company'sCompany’s primary derivative instruments are interest rate instruments used to mitigate variability in earnings due to fluctuations in interest rates and power purchase or sale contracts used to mitigate variability in earnings due to fluctuations in market prices and commodity purchaseprices. Certain derivative contracts used to control customer reimbursable fuel cost.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 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.
Concentrations of Credit Risk
Financial instruments which potentially subject the Company to concentrations of credit risk consist primarily of accounts receivable — trade and derivative 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'sCompany’s projects have only one customer. See Item 1A, Risk Factors, Risks relatedRelated to the Company'sCompany’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 12, Segment Reporting, for concentration of counterparties.
Fair Value of Financial Instruments
The carrying amount of cash and cash equivalents, restricted cash, accounts receivable — trade, accounts payable — trade, account payable — affiliateaffiliates 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'sCompany’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, as of December 31, 2021 and 2020, along with the additions and accretion related to the Company's ARO obligationsactivity for the year ended December 31, 2021:2022:
| | | | | |
| (In millions) | |
Balance as of December 31, 20202021 | $ | 117 | |
Thermal Business AROs reclassified to held for sale | (1) | |
Revisions in estimates for current obligations | 2 | |
Additions | 19146 | |
| |
| Liabilities incurred | 6 | |
| Liabilities settled | (5) | |
Accretion — expense | 910 | |
Balance as of December 31, 20212022 | $ | 146157 | |
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'sCompany’s investment are included within cash flows from operating activities and distributions from equity method investments that represent a return of the Company'sCompany’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.
Business and Asset Acquisitions
The Company accounts for its acquisitions in accordance with ASC 805, Business Combinations, or ASC 805. For third- partythird-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. It also recognizes and measures the goodwill acquired or a gain from a bargain purchase in the business combination and determines what information to disclose to enable users of an entity's financial statements to evaluate the nature and financial effects of the business combination. In addition, for business combinations, transaction costs are expensed as incurred. For asset acquisitions, identifiable assets acquired and liabilities assumed are recorded at acquisition date fair value. 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, ASC 805 requires retrospective combination of the entities for all annual periods presented as if the combination has been in effect from the beginning of the earliest financial statement period presented or from the date the entities were under common control (if later than the beginning of the earliest financial statement period). The difference between the cash paid and historical value of the entities'entities’ equity is recorded as a distribution/contribution from/to CEG with the offset to CEG’s contributed capital balance.
Tax Equity Arrangements
Certain portions of the Company’s redeemable noncontrolling interest.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 statement 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. The following table reflects the changes in the Company’s redeemable noncontrolling interest balance for the year ended December 31, 2022:
| | | | | | | | |
| | (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 | |
Use of Estimates
The preparation of consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions. These estimates and assumptions impact the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities as of the date of the consolidated financial statements. They also impact the reported amounts of net earnings during the reporting periods. Actual results could be different from these estimates.
In recording transactions and balances resulting from business operations, the Company uses estimates based on the best information available. Estimates are used for such items as plant depreciable lives, uncollectible accounts, AROs, acquisition accounting, fair value of financial instruments and legal costs incurred in connection with recorded loss contingencies, among others. In addition, estimates are used to test long-lived assets for impairment and to determine the fair value of impaired assets. As better information becomes available or actual amounts are determinable, the recorded estimates are revised. Consequently, operating results can be affected by revisions to prior accounting estimates.
Certain portions of the Company's noncontrolling interests in subsidiaries 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. Additionally, certain portions of the Company's investments in unconsolidated affiliates reflect the Company's interests in tax equity arrangements, that are not consolidated by the Company, that have been entered into to finance the cost of solar energy systems, under operating leases or PPAs, that are 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 noncontrolling interest and investment in unconsolidated affiliates 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 noncontrolling interests and investment in unconsolidated affiliates 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 noncontrolling interests and investment in unconsolidated affiliates 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 statement of operations using a systematic and rational method over the period during which the investor is expected to achieve its target return.
Reclassification
Certain prior year amounts have been reclassified for comparative purposes.
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.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'sCompany’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, 2021,2022, the Company has appliedintends to apply the amendments to all its eligible contract modifications, where applicable, duringno later than June 30, 2023, the reference rate reform period.LIBOR cessation date. Additionally, the Company has not elected any optional expedients provided in the standard.
Note 3 — Acquisitions and Dispositions
Acquisitions
As further described in Note 2, Summary of Significant Accounting Policies, the Company records the assets acquired and liabilities assumed at acquisition-date fair value, except in the case of acquisitions under common control by CEG, for which assets acquired and liabilities assumed are recorded at historical cost on the acquisition date, which in certain circumstances represent the acquired cost.
The fair value of property, plant and equipment for third-party acquisitions was determined primarily based on an income method using discounted cash flows and validated using a cost approach based on the replacement cost of the assets less economic depreciation. This methodology was utilized as the forecasted cash flows incorporate specific attributes of each asset including age, useful life, equipment condition and technology. The fair value of intangible assets was determined utilizing a variation of the income approach determined by discounting incremental cash flows associated with the contracts to present value. Primary assumptions utilized included estimates of generation, contractual prices, operating expenses and the weighted average cost of capital reflective of a market participant. These assumptions are considered to be a Level 3 measurement as defined in ASC 820, as they utilize inputs that are not observable in the market.
Daggett 3 Drop Down — On February 17, 2023, Daggett Solar Investment LLC, a subsidiary of the Company, acquired the Class A membership interests in Daggett Renewable Holdco LLC from Clearway Renew LLC, a subsidiary of CEG, for cash consideration of $21 million. Simultaneously, Daggett Renewable Holdco LLC acquired Daggett TargetCo LLC, the indirect owner of the Daggett 3 solar project, a 300 MW solar project with matching storage capacity that is currently under construction and located in San Bernardino, California. Daggett Renewable Holdco LLC is a partnership between the Company and a third-party investor. The third-party investor also paid cash consideration of $129 million, which was utilized to acquire the Class B membership interests in Daggett Renewable Holdco LLC. Daggett TargetCo LLC consolidates, as the direct owner of the primary beneficiary, a tax equity fund, Daggett TE Holdco LLC, which holds the Daggett 3 solar project. Daggett 3 has PPAs with investment-grade counterparties that have a 15-year weighted average contract duration that will commence when the project reaches commercial operations, which is expected to occur in the first half of 2023. The acquisition was funded with existing sources of liquidity.
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 with matching storage capacity located in Honolulu, Hawaii, from Clearway Renew LLC for cash consideration of $20 million. Lighthouse Renewable Holdco LLC is a partnership between the Company and a third-party investor. The third-party investor also contributed cash consideration of $12 million, which was utilized to acquire their portion of the acquired entity. Waiawa BL Borrower Holdco LLC consolidates, as the direct owner of the primary beneficiary, a tax equity fund, Waiawa TE Holdco LLC, which directly holds the Waiawa solar project, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. 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 contributed capital 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 members’ 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. 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 to the Company by CEG. Also at acquisition date, the tax equity investor contributed $17 million into escrow, which is included in restricted cash on the Company's consolidated balance sheet at December 31, 2022. The tax equity investor will contribute an additional $41 million when the project reaches substantial completion, which will be utilized, along with the $17 million in escrow, to repay the $55 million tax equity bridge loan. The project is expected to reach substantial completion in the first half of 2023.
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 LLC, whereby Clearway Renew LLC 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 9 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 contributed capital 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 with matching storage capacity located in Honolulu, Hawaii, from Clearway Renew LLC for cash consideration of $22 million. Lighthouse Renewable Holdco LLC is a partnership between the Company and a third-party investor. The third-party investor also contributed cash consideration of $14 million utilized to acquire their portion of the acquired entity. Mililani BL Borrower Holdco LLC consolidates, as the direct owner of the primary beneficiary, a tax equity fund, Mililani TE Holdco LLC, which directly holds the Mililani I solar project, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. 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 contributed capital 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 members’ 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. 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 to the Company by CEG. Also at acquisition date, the tax equity investor contributed $18 million into escrow, which was included in restricted cash on the Company’s consolidated balance sheet. 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.
Black Rock Drop Down — On December 29, 2021, the Company, through its indirect subsidiary Lighthouse Renewable Holding Sub LLC, acquired the Class B membership interests in Black Rock Wind Holding LLC from Clearway Renew LLC a subsidiary of CEG, for $60 million in cash consideration, $37 million of which was paid on December 29, 2021 with the remaining $23 million paid in February 2022 after all remaining turbines were operational. Lighthouse Renewable Holding Sub LLC is a wholly-owned subsidiary of Lighthouse Renewable Holdco LLC, which is a partnership between the Company and a third-party investor. The third-party investor also contributed cash consideration utilized to acquire their portion of the Class B membership interests. The Class A membership interests in Black Rock Wind Holding LLC were acquired by another third-party investor in 2020.2020, which sold their interest back to the Company on March 31, 2022. Black Rock Wind Holding LLC, through its wholly-owned subsidiary, Black Rock Class B Holdco LLC, is the primary beneficiary and consolidates its interests in a tax equity fund, Black Rock TE Holdco LLC, that holds the Black Rock wind project, a 115 MW utility scale wind project located in Mineral County and Grant County, West Virginia, which achieved commercial operations in December 2021, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. As of December 31, 2021, 70 MW of the 115 MW rated capacity were operational, representing fourteen of the twenty-three wind turbines, and the remaining 45 MW rated capacity became operational in January 2022. A majority of the project’s output is backed by contracts with investment-grade counterparties with a 15-year weighted average contract life. The Black Rock operations are reflected in the Company'sCompany’s Renewables segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and not a business combination, therefore the Company consolidated the financial information for Black Rock on a prospective basis. The assets and liabilities transferred to the Company relate to interests under common control by GIP and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the cash paid of $60 million and the historical cost of the Company'sCompany’s acquired interests of $19 million was recorded as an adjustment to CEG'sCEG’s contributed capital balance. In addition, the Company reflected additional contributions paid by CEG and the portion of the Company’s purchase price utilized to repay long-term debt, totaling $133 million, as contributions from CEG in the statement of stockholders’members’ equity, and as an impact of the Black Rock Drop Down in noncontrolling interest.
The following is a summary of assets and liabilities transferred in connection with the acquisition as of December 29, 2021:
| | | | | | | | |
| (In millions) | | Black Rock |
Current assets (a) | | $ | 36 | |
| Property, plant and equipment | | 178 | |
| Right-of-use-assets | | 7 | |
| Other non-current assets | | 2 | |
| Total assets acquired | | 223 | |
| | |
| | |
Long-term debt (b) | | 186 | |
| Long-term lease liabilities | | 7 | |
| Other current and non-current liabilities | | 11 | |
| | |
Total liabilities assumed (c) | | 204 | |
| | |
| Net assets acquired | | $ | 19 | |
(a) Includes $35 million reserved for project completion costs included in restricted cash on the Company'sCompany’s balance sheet at acquisition date, which is included within the $133 million contributed by CEG described above.
(b) Repaid at acquisition date utilizing $56 million contributed by the tax equity investor, $36 million from the cash equity investor and $61 million contributed by CEG, all recorded as contributions in noncontrolling interest, as well as $37 million of the Company'sCompany’s acquisition price. Of the $190 million contributed, $186 million was utilized to pay down the acquired debt and $4 million was utilized to pay associated fees. The $61 million contributed by CEG and the Company’s initial acquisition price of $37 million are also included within the $133 million contributed by CEG described above.
(c) Total liabilities assumed excludes amounts due to CEG as of December 31, 2021the acquisition date for the remaining turbines that became operational in January 2022. The liabilities totaled $83 million, of which $59 million was received from the tax equity and cash equity investors and was held in escrow accounts as of December 31, 2021.the acquisition date.
Mesquite Sky Drop Down — On December 17, 2021, the Company, through its indirect subsidiary Lighthouse Renewable Holdco 2 LLC, acquired the Class B membership interests of Mesquite Sky Holding LLC from Clearway Renew LLC a subsidiary of CEG, for $61 million in cash consideration. Lighthouse Renewable Holdco 2 LLC is a partnership between the Company and a third-party investor. The third-party investor also contributed cash consideration utilized to acquire their portion of the Class B membership interests. The Class A membership interests of Mesquite Sky Holding LLC were acquired by another third-party investor in 2020.2020, which sold their interest back to the Company on March 18, 2022. Mesquite Sky Holding LLC, through its wholly-owned subsidiary, Mesquite Sky Class B Holdco LLC, is the primary beneficiary and consolidates its interests in a tax equity fund, Mesquite Sky TE Holdco LLC, that holds the Mesquite Sky wind project, a 340 MW utility scale wind project located in Callahan County, Texas, which achieved commercial operations in December 2021, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. A majority of the project’s output is backed by contracts with investment-grade counterparties with a 12-year weighted average contract life. The Mesquite Sky operations are reflected in the Company'sCompany’s Renewables segment and the acquisition was funded with existing sources of liquidity. The acquisition was determined to be an asset acquisition and not a business combination, therefore the Company consolidated the financial information for Mesquite Sky on a prospective basis. The assets and liabilities transferred to the Company relate to interests under common control by GIP and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The sum of the cash paid of $61 million and the historical cost of the Company'sCompany’s net liabilities assumed of $7 million was recorded as an adjustment to CEG'sCEG’s contributed capital balance. The difference between cash paid, interests acquired, and the balance in equity is capital reserved for project completion. In addition, the Company reflected additional contributions paid by CEG and the portion of the Company’s purchase price utilized to repay long-term debt, totaling $52 million, as contributions from CEG in the statement of stockholders’members’ equity, and as an impact of the Mesquite Sky drop down in noncontrolling interest.
The following is a summary of assets and liabilities transferred in connection with the acquisition as of December 17, 2021:
| | | | | | | | |
| (In millions) | | Mesquite Sky |
Current assets (a) | | $ | 46 | |
| Property, plant and equipment | | 377 | |
| Right-of use assets | | 45 | |
| Other non-current assets | | 7 | |
| | |
| | |
| Total assets acquired | | 475 | |
| | |
Long-term debt (b) | | 355 | |
| Long-term lease liabilities | | 45 | |
| Derivative liabilities | | 43 | |
| Other current and non-current liabilities | | 39 | |
Total liabilities assumed (c) | | 482 | |
| Net liabilities assumed | | $ | (7) | |
(a) Includes $44 million reserved for project completion costs included in restricted cash on the Company'sCompany’s balance sheet at acquisition date, which is included within the $52 million contributed by CEG described above.
(b) Repaid at acquisition date utilizing $241 million contributed by the tax equity investor and $107 million contributed by the cash equity investor, both recorded as contributions in noncontrolling interest, as well as the Company'sCompany’s $61 million acquisition price. Of the $409 million contributed, $355 million was utilized to pay down the acquired debt and $1 million was utilized to pay associated fees. The remaining $53 million was distributed to CEG for the acquisition. The net of the Company’s $61 million acquisition price and the distribution to CEG of $53 million are included within the $52 million contributed by CEG described above.
(c) Total liabilities assumed excludes amounts due to CEG as of December 31, 2021the acquisition date of $6 million, of which $5 million was received from the tax equity and cash equity investors and was held in escrow accounts as of December 31, 2021.the acquisition date.
Utah Solar Portfolio Acquisition — On December 1, 2021, the Company acquired the remaining 50% equity interest in the Utah Solar Portfolio from Dominion Solar Projects III, Inc., for approximately $335 million before working capital and purchase price adjustments in the net amount of $5 million, representing total net consideration of $330 million. The Utah Solar Portfolio consists of 7seven utility-scale solar farms located in Utah, representing 530 MW of capacity. The assets within the portfolio sell power subject to 20-year PPAs with PacifiCorp that have approximately 15 years remaining under the agreements. Following the close of the transaction, the Company owns 100% of the membership interests in the Utah Solar Portfolio and consolidates the Utah Solar Portfolio. The Utah Solar Portfolio operations are included in the Company'sCompany’s Renewables segment. The acquisition was determined to be an asset acquisition and the cash consideration of $330 million, net of restricted cash acquired of $8 million, represented a net cash outflow of $322 million, which was allocated to the fair value of the assets acquired and liabilities assumed on the acquisition date. The acquisition was funded with the borrowings under the Bridge Loan Agreement, as described in Note 10, Long-term Debt.
The following is a summary of assets and liabilities transferred in connection with the acquisition as of December 1, 2021:
| | | | | | | | |
| (In millions) | | Utah Solar Portfolio |
| Current assets | | $ | 20 | |
| Property, plant and equipment | | 258 | |
| Intangible assets for power purchase agreement | | 302 | |
| Other intangible assets | | 4 | |
| Right-of use assets | | 163 | |
| Total assets acquired | | 747 | |
| | |
| Long-term lease liabilities | | 163 | |
| Other current and non-current liabilities | | 24 | |
| | |
| | |
| | |
| Total liabilities assumed | | 187 | |
| Equity method investment removed | | (230) | |
| Net assets acquired | | $ | 330 | |
Mt. Storm Wind Acquisition — On April 23, 2021, the Company acquired 100% of the equity interests in NedPower Mount Storm LLC, or Mt. Storm, from Castleton Commodities International for approximately $96 million before working capital and purchase price adjustments in the net amount of $4 million, representing a total net consideration of $100 million. Mt. Storm is a 264 MW wind project located in Grant County, West Virginia. Mt. Storm has a 10-year energy hedge with an investment-grade counterparty. The acquisition was determined to be an asset acquisition and the purchase price was allocated to the fair value of the assets acquired and liabilities assumed on the acquisition date as follows:
| | | | | | | | |
| (In millions) | | Mt. Storm |
| | |
| Current assets | | $ | 3 | |
| Property, plant and equipment | | 108 | |
| Other non-current assets | | 2 | |
| | |
| | |
| Total assets acquired | | 113 | |
| | |
| Derivative instruments | | 9 | |
| Other current and non-current liabilities | | 4 | |
| | |
| Total liabilities assumed | | 13 | |
| | |
| Net assets acquired | | $ | 100 | |
Agua Caliente Acquisition — On February 3, 2021, the Company acquired an additional 35% equity interest in the Agua Caliente solar project from NRG Energy, Inc. for $202 million. Agua Caliente is a 290 MW solar project located in Dateland, Arizona in which Clearway previously owned a 16% equity interest. The project has a 25-year PPA with PG&E, with approximately 17 years remaining under the agreement. Following the close of the transaction, the Company owns a 51% equity interest in Agua Caliente. The Agua Caliente operations are included in the Company'sCompany’s Renewables segment. The acquisition was determined to be an asset acquisition and the cash consideration of $202 million, net of restricted cash acquired of $91 million, represented a net cash outflow of $111 million, which was allocated to the fair value of the assets acquired and liabilities assumed on the acquisition date. A third-party investor holds the remaining 49% equity interest in Agua Caliente, which is reflected in noncontrolling interest at fair value at the acquisition date.
The following is a summary of assets and liabilities obtained in connection with the acquisition as of February 3, 2021:
| | | | | | | | |
| (In millions) | | Agua Caliente |
| Restricted cash | | $ | 91 | |
| Property, plant and equipment | | 154 | |
| Intangible asset for power purchase agreement | | 1,022 | |
| | |
| Other current assets | | 9 | |
| Total assets acquired | | 1,276 | |
| | |
| Long-term debt | | 716 | |
| Other current and non-current liabilities | | 5 | |
| | |
| Total liabilities assumed | | 721 | |
| Noncontrolling interest | | 273 | |
| Equity method investment removed | | (80) | |
| Net assets acquired less noncontrolling interest | | $ | 202 | |
Rattlesnake Drop Down — On January 12, 2021, the Company acquired CEG'sCEG’s equity interest and a third-party investor'sinvestor’s minority interest in CWSP Rattlesnake Holding, LLC for $132 million in cash consideration. CWSP Rattlesnake Holding LLC indirectly consolidates the Rattlesnake wind project, a 160 MW wind facility with 144 MW of deliverable capacity in Adams County, Washington, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. The project has a 20-year PPA with Avista Corporation, which began when the facility reached commercial operations in December 2020. The Rattlesnake operations are included in the Company'sCompany’s Renewables segment. The acquisition was determined to be an asset acquisition and not a business combination, therefore, the Company consolidated the financial information for Rattlesnake on a prospective basis. The assets and liabilities transferred to the Company relate to interests under common control by GIP and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the cash paid of $132 million and the historical cost of the Company'sCompany’s acquired interests of $14 million was recorded as an adjustment to CEG'sCEG’s contributed capital balance.
The following is a summary of assets and liabilities transferred in connection with the acquisition as of January 12, 2021:
| | | | | | | | |
| (In millions) | | Rattlesnake |
| Current assets | | $ | 8 | |
| Property, plant and equipment | | 200 | |
| Right-of-use assets | | 12 | |
| Total assets acquired | | 220 | |
| | |
Long-term debt (a) | | 176 | |
| Long-term lease liabilities | | 12 | |
| Other current and non-current liabilities | | 18 | |
| Total liabilities assumed | | 206 | |
| | |
| Net assets acquired | | $ | 14 | |
(a) Repaid at acquisition date utilizing $107 million contributed by tax equity investor and $103 million contributed by CEG, both recorded as contributions in noncontrolling interest. Of the $210 million contributed, $176 million was utilized to pay down the acquired debt, $29 million was utilized to fund project reserve accounts and $5 million was utilized to pay associated fees.
Langford Drop Down — On November 20, 2020, the Company acquired 100% of the Class B membership interest in Langford Holding LLC from CEG for $55 million as well as a minority interest from a third-party investor for $9 million. Langford Holding LLC indirectly consolidates its interest in the Langford wind project as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. The Langford project is a 160 MW wind project located in West Texas which achieved repowering commercial operations in November 2020. The Langford operations are included in the Company's Renewables segment and the acquisition was funded with cash on hand. The acquisition was determined to be an asset acquisition and not a business combination, therefore the Company consolidated the financial information for Langford on a prospective basis. The assets and liabilities transferred to the Company relate to interests under common control by GIP and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the cash paid of $64 million and the historical value of the Company's acquired interests of $21 million was recorded as an adjustment to noncontrolling interest.
The following is a summary of assets and liabilities transferred in connection with the acquisition as of November 20, 2020:
| | | | | | | | |
(In millions) | | Langford |
Current assets | | $ | 4 | |
Property, plant and equipment | | 138 | |
Other non-current assets | | 15 | |
Total assets acquired | | 157 | |
| | |
Other current and non-current liabilities | | 17 | |
Total liabilities assumed | | 17 | |
Noncontrolling interests | | 119 | |
Net assets acquired less noncontrolling interests | | $ | 21 | |
Dispositions
Rosamond Central Drop DownKawailoa Sale — On December 21, 2020, Rosamond Solar Investment LLC, a subsidiary ofAugust 1, 2022, the Company acquiredsold 100% of theits Class A membership interests in the Kawailoa Partnership to Clearway Renew LLC for cash proceeds of Rosie TargetCo LLC from Renew Development HoldCo LLC,$9 million, which equals the Company’s initial investment. The Kawailoa Partnership is a subsidiarypartnership that consolidates, through its 51% controlling majority interest, a lower-level partnership that is 49% owned by a third-party investor, and which consolidates the Kawailoa solar project through its ownership of CEG, for $23 million in cash consideration and an additional $1 million adjustment concurrent with the tax equity investor's final funding which was paid in January 2021. Rosie Target Co LLC is the primary beneficiary and consolidates itsa controlling interest in athe tax equity fund that ownsholds the 192 MW Rosamond Central solar project, located in Kern County, California as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. The Rosamond Central operations are included in the Company's Renewables segment. The acquisition was determined to be an asset acquisition and not a business combination, and therefore, the Company consolidated the financial information for Rosamond Central on a prospective basis. The assets and liabilities transferred to the CompanyClearway Renew LLC relate to interests under common control by GIP and were recordedtransferred at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference betweenThis resulted in the cash paid of $24Company removing $69 million and the historical valuefrom members’ equity, inclusive of the Company's acquirednoncontrolling interest related to the Kawailoa Partnership at the time of sale. Noncontrolling interests prior to the sale include the interests of $28the third-party investor, tax equity investor and Clearway Renew LLC.
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 was recorded as an adjustment to noncontrolling interest.
The following is a summary of assets and liabilities transferredin transaction expenses that were incurred in connection with the acquisition asdisposition. The Thermal Disposition resulted in a gain on sale of December 21, 2020:
| | | | | | | | |
(In millions) | | Rosamond Central |
Current assets | | $ | 49 | |
Property, plant and equipment | | 246 | |
| | |
Other non-current assets | | 1 | |
Total assets acquired | | 296 | |
| | |
Long-term debt | | 205 | |
Other current and non-current liabilities | | 11 | |
Total liabilities assumed | | 216 | |
Noncontrolling interests | | 52 | |
Net assets acquired less noncontrolling interests | | $ | 28 | |
Mesquite Star Drop Down — OnSeptember 1, 2020,business of approximately $1.29 billion, which is net of the Company, through its indirect subsidiary Lighthouse Renewable Class A LLC, acquired the Class A membership interests in Lighthouse Renewable Holdco LLC (formerly Mesquite Star Pledgor LLC) from Clearway Renew LLC, a subsidiary of CEG, for $74$18 million in cash consideration inclusive of a purchase price adjustment received intransaction expenses referenced above. The proceeds from the fourth quarter of 2020 concurrent with the partnership amendment referenced below. Lighthouse Renewable Holdco LLC indirectly owns 100% of the Class B membership interests in Mesquite Star Tax Equity Holdco LLC, a tax equity partnership that it consolidates as the primary beneficiary, and owns the Mesquite Star wind project, a 419 MW utility scale wind project located in Fisher County, Texas. A majority of the project's output is backed by contracts with investment-grade counterparties with a 12 year weighted average contract life. The Mesquite Star operations are reflected in the Company's Renewables segment and the acquisition was funded with cash on hand. The Company initially recorded its interest in Lighthouse Renewable Class A LLC as an equity method investment. The assets and liabilities transferred to the Company relate to interests under common control by GIP andsale were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the $74 million cash paid and the historical value of the Company's acquired interests of $83 million was recorded as an adjustment to noncontrolling interest.
On December 21, 2020, Clearway Renew LLC sold the Class B membership interest in Lighthouse Renewable Holdco LLC to a third-party investor as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. The investor and the Company amended the terms of the related partnership and as a result, the Company now consolidates its interest in the Mesquite Star wind project, through its consolidation of Lighthouse Renewable Holdco LLC. The membership interests acquired by the Company relate to interests under common control by GIP and were recorded at historical cost. The difference between the carrying value of the Company's equity method investment of $58 million and the historical value of the net assets consolidated for Mesquite Star of $63 million was recorded as an adjustment to noncontrolling interest.
The following table shows the balances that were consolidated effective on December 21, 2020:
| | | | | |
(In millions) | Mesquite Star |
Current assets | $ | 22 | |
Property, plant and equipment | 443 | |
Other non-current assets | 31 | |
Total assets acquired | 496 | |
| |
Other current and non-current liabilities | 87 | |
Total liabilities assumed | 87 | |
Noncontrolling interests and redeemable noncontrolling interests | 346 | |
Net assets acquired less noncontrolling interests | $ | 63 | |
DG Residual Interest and SREC Contract Drop Down — On November 2, 2020, the Company acquired the Class B membership interests in DGPV Holdco 1, DGPV Holdco 2 and DGPV Holdco 3, or DGPV Holdco Entities, from Renew DG Holdings LLC, a subsidiary of CEG, for approximately $20 million in cash consideration and an SREC contract for approximately $24 million in cash consideration. The Company previously held the Class A membership interests in the DGPV Holdco Entities and accounted for its interests in DGPV Holdco 1 and DGPV Holdco 2 as equity method investments, while DGPV Holdco 3 was consolidated by the Company effective May 29, 2020 as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. Subsequent to the acquisition of the remaining interests in the DGPV Holdco Entities, the Company transferred its interests to DG-CS Master Borrower LLC, and issued debt that was utilized to repay existing project-level debtcertain borrowings outstanding and unwind interest rate swaps for certain of the tax equity arrangements related to the underlying project funds, as further described in Note 10, Long-term Debt. The acquired SREC contract is a contract to receive incremental, with the remaining proceeds invested in short-term investments classified as cash flows related to renewable energy credits from certain underlying solar projects. The assets and liabilities transferred to the Company relate to interests under common control by GIP and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the cash paid for the residual interest of the DGPV Holdco Entities and the historical value of the net assets consolidated less the carrying value of the equity method investments was recorded as an adjustment to noncontrolling interest.
The following table shows the balances that were consolidated:
| | | | | | | | | | | |
| November 2, 2020 | | May 29, 2020 |
| (In millions) | DGPV Holdco 1 and 2 (a) | | DGPV Holdco 3 (b) |
| Current assets | $ | 29 | | | $ | 32 | |
| Property, plant and equipment, net | 324 | | | 331 | |
| Intangible assets, net | 19 | | | 1 | |
| Other non-current assets | 52 | | | 37 | |
| Total assets acquired | 424 | | | 401 | |
| | | |
| Long-term debt | 160 | | | 206 | |
| Other current and non-current liabilities | 54 | | | 84 | |
| Total liabilities assumed | 214 | | | 290 | |
| Noncontrolling interests and redeemable noncontrolling interests | 5 | | | 6 | |
| Net assets acquired less noncontrolling interests | $ | 205 | | | $ | 105 | |
(a)Includes DGPV 1, LLC, DGPV 2, LLC, CA Fund, LLC, DGPV 4 Borrower LLC and Puma Class B LLC
(b)Includes Renew Solar CS4 Fund LLC and Chestnut Fund LLC
The fair value of property, plant and equipment determined at GIP's acquisition date was determined primarily based on an income method using discounted cash flows and validated using a cost approach basedequivalents on the replacement costCompany’s consolidated balance sheet as of the assets less economic depreciation. This methodology was utilized as the forecasted cash flows incorporate specific attributes of each asset including age, useful life, equipment condition and technology. The fair value of intangible assets was determined utilizing a variation of the income approach determined by discounting incremental cash flows associated with the contracts to present value. Primary assumptions utilized included estimates of generation, contractual prices, operating expenses and the weighted average cost of capital reflective of a market participant. These assumptions are considered to be a Level 3 measurement as defined in ASC 820, as they utilize inputs that are not observable in the market.
Dispositions
Thermal Disposition — On October 22, 2021, Clearway Energy Operating LLC entered into a binding agreement to sell the Thermal Business to KKR for total consideration of $1.9 billion, subject to customary closing adjustments. The closing of the transaction is subject to various customary closing conditions, approvals and consents and is expected to close in the first half ofSeptember 30, 2022. Effective with the approval by the Board of Directors and signing of the agreement to sell the Thermal Business on October 22, 2021, the Company concluded that all entities that are included within the Thermal Business willwould be treated as held for sale on a prospective basis, resulting inthus the assets and liabilities beingwere reported as separate held for sale line items on the Company’s consolidated balance sheet as of December 31, 2021. Property,As of December 31, 2021, property, plant and equipment representsrepresented 78% and intangible assets representsrepresented 9% of assets classified as held for sale while long-term debt representsrepresented 85% of liabilities classified as held for sale. The Company expects to recognize a gain upon the completion of the Thermal Disposition. The Company'sCompany’s Thermal segment is comprised solely of the Thermal Business's results of operations.
Sale of RPV Holdco 1 LLC — On May 14, 2020, the Company sold its interests in RPV Holdco 1 LLC, or RPV Holdco, to Spruce Power for net proceeds of approximately $75 million. The Company previously accounted for its interest in RPV Holdco as an equity method investment. The sale of the investment resulted in a gain of approximately $49 million.
Sale of Energy Center Dover LLC and Energy Center Smyrna LLC Assets — On March 3, 2020, the Company, through Clearway Thermal LLC, sold 100% of its interests in Energy Center Dover LLC and Energy Center Smyrna LLC to DB Energy Assets, LLC for cash proceeds of approximately $15 million.
Note 4 — Property, Plant and Equipment
The Company'sCompany’s major classes of property, plant, and equipment were as follows:
| | | December 31, 2021 | | December 31, 2020 | | Depreciable Lives | | December 31, 2022 | | December 31, 2021 | | Depreciable Lives |
| | (In millions) | | | | (In millions) | | |
| Facilities and equipment | Facilities and equipment | $ | 9,747 | | | $ | 9,254 | | | 2 - 40 Years | Facilities and equipment | $ | 9,992 | | | $ | 9,747 | | | 3 - 40 Years |
| Land and improvements | Land and improvements | 320 | | | 224 | | | Land and improvements | 293 | | | 320 | | |
Construction in progress (a) | Construction in progress (a) | 84 | | | 62 | | | Construction in progress (a) | 160 | | | 84 | | |
| Total property, plant and equipment | Total property, plant and equipment | 10,151 | | | 9,540 | | | Total property, plant and equipment | 10,445 | | | 10,151 | | |
| Accumulated depreciation | Accumulated depreciation | (2,501) | | | (2,323) | | | Accumulated depreciation | (3,024) | | | (2,501) | | |
| Net property, plant and equipment | Net property, plant and equipment | $ | 7,650 | | | $ | 7,217 | | | Net property, plant and equipment | $ | 7,421 | | | $ | 7,650 | | |
(a) As of December 31, 20212022 and 2020,2021, construction in progress includes $17 million and $14$15 million, respectively, of capital expenditures that relate to prepaid long-term service agreements in the Conventional segment.
Depreciation expense related to property, plant and equipment during the years ended December 31, 2022, 2021 and 2020 and 2019 was $502 million, $499 million $420 million and $395$420 million, respectively. The Company accelerated depreciation of the Pinnacle wind project in connection with the repowering project, which resulted in additional depreciation expense in the amount of $34 million in 2021 and $9 million in 2020.2021.
The Company recorded long-lived asset impairments during each of the years ended December 31, 20212022 and December 31, 2020,2021, as further described in Note 9, Asset Impairments.
Note 5 — Investments Accounted for by the Equity Method and Variable Interest Entities
Equity Method Investments
The Company'sCompany’s maximum exposure to loss as of December 31, 20212022 is limited to its equity investment in the unconsolidated entities, as further summarized in the table below:
| | Name | Name | | Economic Interest | | Investment Balance | Name | | Economic Interest | | Investment Balance |
| | | | | (In millions) | | | | | (In millions) |
| Avenal | Avenal | | 50% | | $ | 4 | | Avenal | | 50% | | $ | 9 | |
| Desert Sunlight | Desert Sunlight | | 25% | | 239 | | Desert Sunlight | | 25% | | 235 | |
| Elkhorn Ridge | Elkhorn Ridge | | 66.7% | | 29 | | Elkhorn Ridge | | 66.7% | | 22 | |
GenConn (a) | GenConn (a) | | 50% | | 86 | | GenConn (a) | | 50% | | 82 | |
| San Juan Mesa | San Juan Mesa | | 75% | | 23 | | San Juan Mesa | | 75% | | 16 | |
| | $ | 381 | | | $ | 364 | |
(a) GenConn is a variable interest entity.
As of December 31, 20212022 and 2020,2021, the Company had $14$19 million and $10$14 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 $171$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, 2022, the carrying value of the basis difference is $129 million.
The Company'sCompany’s pro-rata share of non-recourse debt held by unconsolidated affiliates was $345$325 million as of December 31, 2021.2022.
The following tables present summarized financial information for the Company'sCompany’s equity method investments:
| | | Year Ended December 31, | | Year Ended December 31, |
| | 2021 | | 2020 | | 2019 | | 2022 | | 2021 | | 2020 |
| Income Statement Data: | Income Statement Data: | (In millions) | Income Statement Data: | (In millions) |
| GenConn | GenConn | | GenConn | |
| Operating revenues | Operating revenues | $ | 55 | | | $ | 60 | | | $ | 60 | | Operating revenues | $ | 50 | | | $ | 55 | | | $ | 60 | |
| Operating income | Operating income | 22 | | | 26 | | | 27 | | Operating income | 16 | | | 22 | | | 26 | |
| Net income | Net income | 13 | | | 17 | | | 17 | | Net income | 7 | | | 13 | | | 17 | |
| Desert Sunlight | Desert Sunlight | | Desert Sunlight | |
| Operating revenues | Operating revenues | 205 | | | 209 | | | 205 | | Operating revenues | 203 | | | 205 | | | 209 | |
| Operating income | Operating income | 146 | | | 142 | | | 123 | | Operating income | 137 | | | 146 | | | 142 | |
| Net income | Net income | 112 | | | 88 | | | 58 | | Net income | 114 | | | 112 | | | 88 | |
| Other (a) (b) | Other (a) (b) | | Other (a) (b) | |
| Operating revenues | Operating revenues | 49 | | | 299 | | | 318 | | Operating revenues | 52 | | | 49 | | | 299 | |
| Operating income | Operating income | 16 | | | 138 | | | 110 | | Operating income | 18 | | | 16 | | | 138 | |
| Net income | Net income | $ | 13 | | | $ | 60 | | | $ | 50 | | Net income | 15 | | | 13 | | | 60 | |
| | | As of December 31, | | As of December 31, |
| | 2021 | | 2020 | | 2022 | | 2021 |
| Balance Sheet Data: | Balance Sheet Data: | | (In millions) | Balance Sheet Data: | | (In millions) |
| GenConn | GenConn | | GenConn | |
| Current assets | Current assets | | $ | 38 | | | $ | 40 | | Current assets | | $ | 39 | | | $ | 38 | |
| Non-current assets | Non-current assets | | 328 | | | 344 | | Non-current assets | | 312 | | | 328 | |
| Current liabilities | Current liabilities | | 15 | | | 17 | | Current liabilities | | 16 | | | 15 | |
| Non-current liabilities | Non-current liabilities | | 178 | | | 185 | | Non-current liabilities | | 170 | | | 178 | |
| Desert Sunlight | Desert Sunlight | | Desert Sunlight | |
| Current assets | Current assets | | 131 | | | 132 | | Current assets | | 79 | | | 131 | |
| Non-current assets | Non-current assets | | 1,228 | | | 1,244 | | Non-current assets | | 1,175 | | | 1,228 | |
| Current liabilities | Current liabilities | | 64 | | | 71 | | Current liabilities | | 61 | | | 64 | |
| Non-current liabilities | Non-current liabilities | | 904 | | | 921 | | Non-current liabilities | | 824 | | | 904 | |
| Other (a) (b) | | |
Other (a) | | Other (a) | |
| Current assets | Current assets | | 26 | | | 177 | | Current assets | | 22 | | | 26 | |
| Non-current assets | Non-current assets | | 172 | | | 2,201 | | Non-current assets | | 157 | | | 172 | |
| Current liabilities | Current liabilities | | 24 | | | 114 | | Current liabilities | | 12 | | | 24 | |
| Non-current liabilities | Non-current liabilities | | 98 | | | 700 | | Non-current liabilities | | 91 | | | 98 | |
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(a) Includes Avenal, Elkhorn Ridge, San Juan Mesa, DGPV Holdco 1, DGPV Holdco 2 and DGPV Holdco 3. DGPV Holdco 1, DGPV Holdco 2 and DGPV Holdco 3 were consolidated by the Company during 2020 and are therefore excluded fromonly included in the summarized balance sheetincome statement data as offor the year ended December 31, 2020.
(b) On February 3, 2021, the Company acquired an additional 35% equity interest in Agua Caliente and removed its equity investment in Agua Caliente and, on December 1, 2021, the Company acquired the remaining 50% equity investment in the Utah Solar Portfolio and removed its equity investment in the Utah Solar Portfolio. As a result, both Agua Caliente and the Utah Solar Portfolio are excluded from the summarized balance sheet data as of December 31, 2021 and from the summarized income statement data for the yearyears ended December 31, 2022 and December 31, 2021.
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 or ASC 810.. 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 facilitiesfacilities. 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 are further described below.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.
Summarized financial information forThe following is a summary of significant activity during 2022 related to the Company'sCompany’s consolidated VIEs consisted of the following as of December 31, 2021:VIEs:
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| (In millions) | Alta TE Holdco | | Buckthorn Renewables, LLC | | DGPV Funds(a) | | Kawailoa Partnership | | Langford TE Partnership LLC | | Lighthouse Renewable Holdco LLC(b) | | Lighthouse Renewable Holdco 2 LLC(c) |
| Other current and non-current assets | $ | 53 | | | $ | 4 | | | $ | 104 | | | $ | 40 | | | $ | 17 | | | $ | 84 | | | $ | 83 | |
| Property, plant and equipment | 331 | | | 202 | | | 592 | | | 135 | | | 132 | | | 605 | | | 377 | |
| Intangible assets | 212 | | | — | | | 16 | | | — | | | 2 | | | — | | | — | |
| Total assets | 596 | | | 206 | | | 712 | | | 175 | | | 151 | | | 689 | | | 460 | |
| Current and non-current liabilities | 40 | | | 10 | | | 76 | | | 103 | | | 18 | | | 150 | | | 118 | |
| Total liabilities | 40 | | | 10 | | | 76 | | | 103 | | | 18 | | | 150 | | | 118 | |
| Noncontrolling interest | 13 | | | 44 | | | 6 | | | 48 | | | 66 | | | 416 | | | 239 | |
| Net assets less noncontrolling interests | $ | 543 | | | $ | 152 | | | $ | 630 | | | $ | 24 | | | $ | 67 | | | $ | 123 | | | $ | 103 | |
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(a)DGPV Funds is comprised of DGPV Fund 2 LLC, Clearway & EFS Distributed Solar LLC, DGPV Fund 4 LLC, Golden Puma Fund LLC, Renew Solar CS4 Fund LLC and Chestnut Fund LLC.
(b)Lighthouse Renewable Holdco LLC — The Company, through its indirect, wholly-owned subsidiary, Lighthouse Renewable Class A LLC, holds the Class A membership interests of Lighthouse Renewable Holdco LLC, while a third-party investor holds the Class B membership interests. The Company consolidates Lighthouse Renewable Holdco LLC, which is a VIE, as the Company is the primary beneficiary, through its role as managing member.
In addition, Lighthouse Renewable Holdco LLC indirectly holds the Class B membership interests in several tax equity funds, including Mesquite Star Tax Equity Holdco LLC, and Black Rock TE Holdco LLC, which are also consolidated VIEs.
(c)Lighthouse Renewable Holdco 2 LLC consolidates Mesquite SkyMililani TE Holdco LLC which is also a consolidated VIE.
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| (In millions) | Oahu
Solar Partnership | | Pinnacle Repowering Partnership LLC | | Rattlesnake TE Holdco LLC | | Rosie Target Co LLC | | Wildorado TE Holdco | | Other(a) |
| Other current and non-current assets | $ | 47 | | | $ | 12 | | | $ | 30 | | | $ | 26 | | | $ | 21 | | | $ | 16 | |
| Property, plant and equipment | 172 | | | 108 | | | 194 | | | 251 | | | 225 | | | 168 | |
| Intangible assets | — | | | 18 | | | — | | | — | | | — | | | 1 | |
| Total assets | 219 | | | 138 | | | 224 | | | 277 | | | 246 | | | 185 | |
| Current and non-current liabilities | 114 | | | 6 | | | 23 | | | 100 | | | 18 | | | 44 | |
| Total liabilities | 114 | | | 6 | | | 23 | | | 100 | | | 18 | | | 44 | |
| Noncontrolling interest | 31 | | | 78 | | | 98 | | | 140 | | | 121 | | | 84 | |
| Net assets less noncontrolling interests | $ | 74 | | | $ | 54 | | | $ | 103 | | | $ | 37 | | | $ | 107 | | | $ | 57 | |
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(a)Other is comprised of Crosswind Transmission, LLC, Hardin Hilltop Wind LLC, Elbow Creekand Waiawa TE Holdco and Spring Canyon TE Holdco projects.
Pinnacle Repowering Partnership LLC, — On February 26, 2021, the Company entered into an amended agreement with CWSP Pinnacle Holding LLC, an indirect subsidiary of CEG, with respect to Pinnacle Repowering Partnership LLC in order to facilitate the repowering of the Pinnacle wind project, a 54 MW wind facility located in Mineral County, West Virginia. On March 10, 2021, the Company contributed its interest in the Pinnacle wind project to Pinnacle Repowering Partnership LLC concurrent with entering into a financing agreement as further described in Note 7, Long-term Debt. The Company owns 100% of the Class A membership interests in Pinnacle Repowering Partnership LLC, which is a VIE, and the Company consolidates its interest as the primary beneficiary and managing member. CWSP Pinnacle Holding LLC owns 100% of the Class B membership interests in Pinnacle Repowering Partnership LLC and is entitled to allocations of 15% of the cash distributions from the partnership. On March 10, 2021, CWSP Pinnacle Holding LLC contributed $27 million in equipment to the partnership, which was a transfer of assets under common control and recorded at historical cost in property, plant and equipment, with a corresponding non-cash contribution in Pinnacle Repowering Partnership LLC's noncontrolling interests. Additionally, on March 10, 2021, the Pinnacle wind project acquired equipment from CEG for $21 million in cash consideration.below.
On December 15, 2021, in connection with the completion of the repowering of the project, a third-party tax equity investor acquired the Class A membership interests in Pinnacle Tax Equity Holdco LLC, which is a tax equity fund, and the holder of the Pinnacle wind project, for $48 million. The Company consolidates Pinnacle Tax Equity Holdco LLC, as primary beneficiary through its consolidated subsidiary Pinnacle Repowering Partnership LLC, who acts as managing member. In addition, upon completion of the repowering, the Company made a payment of $64 million, which was utilized along with the proceeds of the tax equity investment to repay the outstanding debt under the financing agreement referenced above. The Company utilizes the HLBV method to determine the net income or loss allocated to tax equity noncontrolling interest.
Rattlesnake TE Holdco LLC — As described in Note 3, Acquisitions and Dispositions, on January 12, 2021, the Company acquired CEG's equity interest and a third-party investor's minority interest in CWSP Rattlesnake Holding LLC for $132 million. CWSP Rattlesnake Holding LLC owns Rattlesnake Class B LLC, which owns the Class B membership interests in Rattlesnake TEMarch 25, 2022, Lighthouse Renewable Holdco LLC which is a VIE. Rattlesnake Class B LLC is the primary beneficiary and managing member and consolidates its interest in Rattlesnake TEacquired Mililani BL Borrower Holdco LLC, which owns the Rattlesnake wind project. Subsequent to the acquisition, on January 12, 2021 the third-party tax equity investor contributed $107 million into Rattlesnake TE Holdco LLC in exchange for the Class A membership interests. The proceeds from the tax equity contribution along with cash contributed by CEG were used to repay a portion of the $176 million of the outstanding principal under the Rattlesnake Class B LLC credit facility. The Company utilizes the HLBV method to determine the net income or loss allocated to tax equity noncontrolling interest.
DGPV Holdco 3 Consolidation — DGPV Holdco 3 LLC or DGPV Holdco 3 owned approximately 113 MW of Distributed Solar capacity, based on cash to be distributed, with a weighted average remaining contract life of approximately 21 years. On May 29, 2020, the final construction projects for DGPV Holdco 3 were placed in service which resulted in a reconsideration event for consolidation of the entity. Upon the reconsideration event, the Company determined that it was the primary beneficiary of DGPV Holdco 3, as it is entitled to 99% of allocations of income and cash distributions from the entity. As such, effective on May 29, 2020, the Company consolidates DGPV Holdco 3, and records the interest owned by CEG as noncontrolling interest. DGPV Holdco 3 owns an interest in two tax equity funds with tax equity investors, both of which are consolidated by DGPV Holdco 3, and the interests owned by the tax equity investors are shown as noncontrolling interests. The Company removed its equity method investment in DGPV Holdco 3 of $155 million as of May 29, 2020 and recorded the difference between the net assets consolidated and the investment balance as a reduction to noncontrolling interests. The Company acquired CEG's interest in DGPV Holdco 3 on November 2, 2020 as further described in Note 3, Acquisitions and Dispositions and below.
Prior to the reconsideration event described above, the Company invested $10 million of cash in DGPV Holdco 3 during the first half of 2020.
DGPV Tax Equity Funds — As described in Note 3, Acquisitions and Dispositions, on November 2, 2020, the Company acquired the Class B membership interests in DGPV Holdco 1, DGPV Holdco 2 and DGPV Holdco 3, or the DGPV Holdco Entities, from Renew DG Holdings LLC, a subsidiary of CEG. The Company previously held the Class A membership interests in the DGPV Holdco Entities and accounted for its interests in DGPV Holdco 1 and DGPV Holdco 2 as equity method investments, while DGPV Holdco 3 was consolidated by the Company effective May 29, 2020 as further described above. Concurrent with the acquisition, the Company transferred its interests to DG-CS Master Borrower LLC. Effective with the acquisitionindirect owner of the Class B membership interests of the DGPV Holdco Entities, the Company consolidates all of the DGPV Holdco Entities, including DG-CS Master Borrower LLC, and its subsidiaries, which consist of 7 projects including 6a tax equity fundsfund, Mililani TE Holdco LLC, that collectively own approximately 172 distributedholds the Mililani I solar projects with a combined 286 MW of capacity. Each of the 6 tax equity fundsproject. Mililani BL Borrower Holdco LLC consolidates Mililani TE Holdco LLC, which is a VIE, where the Company is the primary beneficiary and consolidates the fund, with the tax equity investor's interest shown as noncontrolling interest or redeemable noncontrolling interest. The Company utilizes the HLBV method to determine its share of the income or losses in the investees. The Company removed its equity method investments in DGPV Holdco 1 and DGPV Holdco 2 of $144 million as of November 2, 2020 and recorded the difference between the net assets consolidated and the investment balance as a reduction to noncontrolling interests.
Langford Tax Equity Partnership, LLC — As described in Note 3, Acquisitions and Dispositions, on November 20, 2020, the Company acquired 100% of the Class B membership interest in Langford Holding LLC from CEG for $55 million as well as 100% of the Class A membership interests in Langford Holding LLC from a third-party investor for $9 million. Langford Holding LLC owns 100% of the membership interests in Langford Class B Holdco LLC, which owns 100% of the Class B interest in Langford Tax Equity Partnership LLC, which indirectly owns 100% of the interest in a 160 MW wind project. Langford Tax Equity Partnership LLC is a variable interest entity. The Companyit is the primary beneficiary through its positionrole as managing member, and indirectly consolidates Langford Tax Equity Partnership LLC, through Langford Class B Holdco LLC.member. The Class A member ismembership interests are held by a tax equity investor whose interest isand are reflected as noncontrolling interest on the Company'sCompany’s consolidated balance sheet. The project achieved repowering COD in November 2020. The Company utilizes the HLBV method for income or loss allocation to the tax equity investor's noncontrolling interest.
Lighthouse Partnership Arrangements
Lighthouse Renewable Holdco LLC — As described in Note 3, Acquisitions and Dispositions, onSeptember 1, 2020, the Company, through its indirect subsidiary Lighthouse Renewable Class A LLC, acquired the Class A membership interests in Lighthouse Renewable Holdco LLC (formerly Mesquite Star Pledgor LLC) from Clearway Renew LLC, a subsidiary of CEG. Lighthouse Renewable Holdco LLC is a VIE and at the time of the acquisition the Company was not the primary beneficiary. Accordingly, the Company recorded the acquired interest as an equity method investment.
On December 21, 2020, CEG sold its Class B membership interest in Lighthouse Renewable Holdco LLC to a third-party investor which resulted in a reconsideration event for consolidation of the entity. Upon the reconsideration event, the Company determined that it was the primary beneficiary of Lighthouse Renewable Holdco LLC. As such, effective on December 21, 2020, the Company consolidates Lighthouse Renewable Holdco LLC, and shows the Class B interests owned by the third-party investor as noncontrolling interests on the Company’s consolidated balance sheet. Through its Class A membership interests, the Company receives 50.01% of income and distributable cash. In addition, Lighthouse Renewable Holdco LLC holds the Class B interests in a tax equity fund, Mesquite Star Tax Equity Holdco LLC, that holds the Mesquite Star project. The tax equity investor's interest is shown as noncontrolling interest. The HLBV method is utilized to allocate the income or losses of Mesquite Star Tax Equity Holdco LLC. As described in Note 3, Acquisitions and Dispositions, on December 29, 2021, Lighthouse Renewable Holdco LLC, through its indirect wholly-owned subsidiary, Lighthouse Renewable Holding Sub LLC, acquired the Class B interests in a partnership, Black Rock Wind Holding LLC, which consolidates, as the direct owner of the primary beneficiary, a tax equity fund, Black Rock TE Holdco LLC, that holds the Black Rock wind project. The tax equity investor’s interest is shown as noncontrolling interest and the HLBV method is utilized to allocate the income or losses of Black Rock TE Holdco LLC. As described in Note 3, Acquisitions and Dispositions, the third-party investor in Lighthouse Renewable Holdco LLC also acquired and contributed an interest in Black Rock Wind HoldingMililani BL Borrower Holdco LLC to Lighthouse Renewable Holdco LLC. The Company recorded the related noncontrolling interest at historical carrying amount, with the offset to contributed capital.
Lighthouse Renewable Holdco 2 LLC— On December 17, 2021, the Company formed Lighthouse Renewable Holdco 2 LLC, a partnership between the Company and a third-party investor. Lighthouse Renewable Holdco 2 LLC is a VIE and the Company is the primary beneficiary, through its role as managing member. As described in Note 3, Acquisitions and Dispositions, on December 17, 2021,October 3, 2022, Lighthouse Renewable Holdco 2 LLC acquired Waiawa BL Borrower Holdco LLC, the indirect owner of the Class B membership interests in a partnership, Mesquite Sky Holding LLC, which consolidates, as the direct owner of the primary beneficiary, a tax equity fund, Mesquite SkyWaiawa TE Holdco LLC, that holds the Mesquite Sky windWaiawa solar project. Waiawa BL Borrower Holdco LLC consolidates Waiawa TE Holdco LLC, which is a VIE, as it is the primary beneficiary through its role as managing member. The Class A membership interests are held by a tax equity investor’s interest is showninvestor and are reflected as noncontrolling interest andon the HLBV method is utilized to allocate the income or losses of Mesquite Sky TE Holdco LLC. As described in Note 3, Acquisitions and Dispositions, theCompany’s consolidated balance sheet. The third-party investor in Lighthouse Renewable Holdco 2 LLC also acquired and contributed an interest in Mesquite Sky HoldingWaiawa BL Borrower Holdco LLC to Lighthouse Renewable Holdco 2 LLC. The Company recorded the related noncontrolling interest at historical carrying amount, with the offset to contributed capital.
Rosie TargetCo LLC Kawailoa Partnership — As described in Note 3,Acquisitions and Dispositions,on December 21, 2020,August 1, 2022, the Company acquiredsold 100% of CEG's Class A membership interests of Rosie TargetCo LLC which owns 100% interest in Rosie Class B LLC, which in turn owns 100% of the Class B membership interest of Rosie TE Holdco LLC. The Company consolidates Rosie TargetCo LLC as a VIE as the Company is the primary beneficiary, through its role as managing member. The Class B membership interest of Rosie TargetCo LLC is owned by a third-party investor and is reflected as noncontrolling interest on the Company’s consolidated balance sheet. Through its Class A membership interests in Rosie TargetCo LLC, the Company receives 50% of income and distributable cash. Rosie TargetCo indirectly consolidates Rosie TE Holdco LLC, which is also a VIE. The tax equity investor's interest is shown as noncontrolling interest. The HLBV method is utilized to allocate the income or losses of Rosie TE Holdco LLC.
Kawailoa Partnership — On August 31, 2018, the Company entered into an agreement with Clearway Renew LLC, a subsidiary of CEG, to acquire the Class A membership interests in the Kawailoa Solar Partnership LLC, or the Kawailoa Partnership, for $9 million in cash consideration. The purpose ofto Clearway Renew LLC. Prior to the partnership is to own, finance, operate, and maintainsale, the Kawailoa Solar project, a 49 MW utility-scale solar generation project, an indirect subsidiaryPartnership owned 51% of the Kawailoa Partnership, located in Oahu, Hawaii. The Kawailoa Solarsolar project, is contracted to sell power under a 22-year PPA with Hawaiian Electric Company, or HECO. The Kawailoa Solar project is 51% owned by the Kawailoa Partnership, with the remaining 49% owned by a third-party investor. The Kawailoa Partnership consolidatesconsolidated the Kawailoa Solarsolar project through its controlling majority interest. On May 7, 2019,ownership of the Company made an initial capital contribution of $2 million, which represents 20% of its total anticipated capital contributions. The Company assumed non-recourse debt of $120 million, as further described in Note 10, Long-term Debt,Class B membership interests and non-controlling interests attributable to third parties in the amount of $21 million. Effective May 1, 2019, the Company, as a Class A member, is the primary beneficiary through its positionrole as managing member and consolidates Kawailoa Partnership. Allocations of income and taxable items are equal to the distributions of available cash, which is currently 95% to the Company and 5% to Clearway Renew LLC. The Company's acquisition of the Class A membership interests in the Kawailoa Partnership was accounted for as a transfer of assets under common control and was recorded at historical cost in accordance with ASC 805-50, Business Combinations — Related Issues. The difference between the cash paid and payable recorded and the historical value of the assets was recorded as a distribution to CEG and decreased the balance of its noncontrolling interest.
Upon reaching COD in November of 2019, the Kawailoa Solar project's fixed assets were placed in service and began to depreciate. On December 22, 2019, Kawailoa Solar Holdings LLC, a tax equity fund, received its final equity contribution of $61 million. The proceeds were utilized to repay the ITC bridge loan in the amount of $57 million, and the construction debt was converted to term debt (and upsized, with an additional $5 million drawn). Distributions were paid to the third-party investor and Clearway Renew LLC, funded by the excess of the tax equity investment and the term loan upsizing above the amount of the bridge loan repayment and related fees. On December 27, 2019, the Company made its substantial completion contribution of $7 million intowhich owns the Kawailoa Partnership, which was also utilized to make a distribution to Clearway Renew LLC. In addition, the Company started applying HLBV to allocate income attributable to the tax equity investor during the fourth quarter of 2019.
Oahu Partnership — On August 31, 2018, the Company entered into an agreement with Clearway Renew LLC, a subsidiary of CEG, to acquire thesolar project. The Class A membership interests in the Zephyr Oahu PartnershipKawailoa Solar Holdings LLC or Oahu Partnership, for $20 million in cash consideration. The purpose of the partnership is to own, finance, operate, and maintain the Oahu Solar projects, which consist of Lanikuhana and Waipio, utility-scale solar generation projects with rated capacity of 15 MW and 46 MW, respectively, the indirect subsidiaries of the Oahu Partnership, located in Oahu, Hawaii. The Oahu Solar projects are contracted to sell power under a 22-year PPA with HECO. The Oahu Partnership consolidates the Oahu Solar projects through its controlling majority interest. On March 8, 2019, the Company made an initial capital contribution of $4 million, which represents 20% of its total anticipated capital contributions. The Company also assumed non-recourse debt of $143 million, as further described in Note 10, Long-term Debt, and $18 million of non-controlling interest attributable toheld by a tax equity investor's initial contribution. Effective March 8, 2019,investor and were reflected as noncontrolling interest on the Company’s consolidated balance sheet. The Company, as athe Class A member, iswas the primary beneficiary through its positionrole as managing member and consolidates Oahuconsolidated the Kawailoa Partnership. Allocations of income and taxable items are equal to
Summarized financial information for the distributions of available cash, which is currently 95% to the Company and 5% to Clearway Renew LLC. The Company's acquisitionCompany’s consolidated VIEs consisted of the Class A membership interests in the Oahu Partnership was accounted forfollowing as a transfer of assets under common controlDecember 31, 2022:
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| (In millions) | Alta TE Holdco | | Buckthorn Holdings, LLC | | DGPV Funds (a) | | Langford TE Partnership LLC | | Lighthouse Renewable Holdco LLC (b) | | Lighthouse Renewable Holdco 2 LLC (c) |
| Other current and non-current assets | $ | 51 | | | $ | 2 | | | $ | 75 | | | $ | 13 | | | $ | 134 | | | $ | 49 | |
| Property, plant and equipment | 306 | | | 194 | | | 493 | | | 123 | | | 828 | | | 358 | |
| Intangible assets | 200 | | | — | | | 14 | | | 2 | | | — | | | — | |
| Total assets | 557 | | | 196 | | | 582 | | | 138 | | | 962 | | | 407 | |
| Current and non-current liabilities | 38 | | | 11 | | | 66 | | | 53 | | | 364 | | | 134 | |
| Total liabilities | 38 | | | 11 | | | 66 | | | 53 | | | 364 | | | 134 | |
| Noncontrolling interest | 39 | | | 29 | | | 13 | | | 59 | | | 487 | | | 230 | |
| Net assets less noncontrolling interests | $ | 480 | | | $ | 156 | | | $ | 503 | | | $ | 26 | | | $ | 111 | | | $ | 43 | |
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(a)DGPV Funds is comprised of Clearway & EFS Distributed Solar LLC, DGPV Fund 4 LLC, Golden Puma Fund LLC, Renew Solar CS4 Fund LLC and was recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the cash paid and payable recorded and the historical value of the assets was recorded as a contribution from CEG and increased the balance of its noncontrolling interest.
Upon reaching COD in September 2019, the Oahu Solar projects' fixed assets were placed in service and began to depreciate. On November 12, 2019, theChestnut Fund LLC, which are all tax equity investor made its final tax-equity contribution of $71 million and the proceeds were utilized to repay the related ITC bridge loan in the amount of $67 million, and the construction loan was converted to term debt. The Company paid the remaining 80% of the equity commitment in the amount of $16 million to Clearway Renew LLC when the Oahu Solar projects reached certain milestones in December 2019. In addition, the Company started applying HLBV to allocate income attributable to the tax equity investor during the third quarter of 2019.funds.
Repowering Partnership II LLC — On August 30, 2018, Wind TE Holdco, an indirect subsidiary of the Company, formed Repowering Partnership LLC with Clearway Renew LLC, an indirect subsidiary of CEG, in order to facilitate the repowering of wind facilities of two of its indirect subsidiaries, Elbow Creek Wind Project LLC, or Elbow Creek, and Wildorado Wind LLC, or Wildorado Wind. Wind TE Holdco contributed its interests in the two facilities and Clearway Renew LLC contributed a turbine supply agreement, including title to certain components that qualify for production tax credits. Wind TE Holdco is the managing member of the partnership and consolidates the entity, which is a VIE. Clearway Renew LLC is initially entitled to allocations of 21% of income, which is reflected in Wind TE Holdco’s noncontrolling interests.
On June 14, 2019, Repowering Partnership LLC was replaced with Repowering Partnership II LLC as the owner of the Elbow Creek and Wildorado Wind projects as well as Repowering PartnershipLighthouse Renewable Holdco LLC which concurrently entered into a financing agreement for construction debt commitment totaling $352 million, as further described in Note 10, Long-term Debt.
Repowering of the Elbow Creek project was completed and on November 26, 2019, a third-party tax equity investor purchased 100% of the Class A membership interests in Elbow Creek Repoweringconsolidates Mesquite Star Tax Equity Holdco LLC, or Elbow TE Holdco for $89 million pursuant to a membership interest purchase agreement dated June 14, 2019. The Company also contributed $4 million. In connection with the completion of the Elbow Creek repowering, the construction loan of $93 million was repaid with the proceeds from the combined proceeds from the tax equity investor and the Company. The Company began applying HLBV during the fourth quarter to allocate income between the partners of Elbow TE Holdco. In connection with the closing, the allocations of income at Repowering Partnership II LLC (which indirectly consolidates both projects) changed to 59.63% for WindBlack Rock TE Holdco LLC, (the Company member) and 40.37% for CWSP Wildorado Elbow Holding LLC (the CEG member). In addition, approximately half of the repowered Wildorado equipment was placed in service in December 2019, with the remaining equipment being placed in service in January of 2020. In connection with repowering of the projects, the Company revised the remaining useful life of the property, plant and equipment that was replaced, resulting in additional expense of $54 million during the year ended December 31, 2019 related to accelerated depreciation.
On February 7, 2020, a third- party tax equity investor purchased 100% of the Class A membership interests in Wildorado TE Holdco, for $148 million. In addition, the Company contributed $112 million to Wildorado TE Holdco. The combined proceeds were used to repay construction debt under the Repowering Partnership Holdco credit agreement, as described in Note 10, Long-term Debt. The third-party tax equity investor, or Wildorado Investor, will receive 99% of allocations of taxable income and other items until the Wildorado Investor obtains a specified return on its initial investment, or the last day of the PTC period, whichever occurs sooner. At such time, the allocations to the Wildorado Investor will change to 5%. Until such time, the Wildorado Investor will receive a variable percentage of cash distributions. Wildorado TE Holdco is a VIE and the Repowering Partnership II LLC is the primary beneficiary through its position as managing member. As a result, the Company consolidates Wildorado TE Holdco, with the Wildorado Investor's interest shown as noncontrolling interest. In connection with the Wildorado TE Holdco closing, the allocations of income at Repowering Partnership II LLC changed to 60.14% for WindMililani TE Holdco LLC (the Company member) and 39.86% for CWSP Wildorado Elbow HoldingWaiawa TE Holdco LLC, (the CEG member).which are consolidated VIEs.
On May 11, 2020, the Company acquired CEG's interest in Repowering Partnership II(c)Lighthouse Renewable Holdco 2 LLC for cash consideration of $70 million. Repowering Partnership IIconsolidates Mesquite Sky TE Holdco LLC, is no longer a VIE and subsequent to the acquisition,which is a wholly-owned subsidiaryconsolidated VIE.
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| (In millions) | Oahu Solar LLC | | Pinnacle Repowering TE Holdco | | Rattlesnake TE Holdco LLC | | Rosie TargetCo LLC | | Wildorado TE Holdco | | Other (a) |
| Other current and non-current assets | $ | 39 | | | $ | 9 | | | $ | 13 | | | $ | 43 | | | $ | 20 | | | $ | 15 | |
| Property, plant and equipment | 164 | | | 102 | | | 185 | | | 238 | | | 209 | | | 154 | |
| Intangible assets | — | | | 16 | | | — | | | — | | | — | | | 1 | |
| Total assets | 203 | | | 127 | | | 198 | | | 281 | | | 229 | | | 170 | |
| Current and non-current liabilities | 22 | | | 5 | | | 17 | | | 101 | | | 18 | | | 69 | |
| Total liabilities | 22 | | | 5 | | | 17 | | | 101 | | | 18 | | | 69 | |
| Noncontrolling interest | 26 | | | 43 | | | 91 | | | 133 | | | 110 | | | 70 | |
| Net assets less noncontrolling interests | $ | 155 | | | $ | 79 | | | $ | 90 | | | $ | 47 | | | $ | 101 | | | $ | 31 | |
| | | | | | | | | | | |
| | | | | | | | | | | |
| | | | | | | | | | | |
(a)Other is comprised of the Company. Repowering Partnership II LLC continues to own interests in two VIEs, Wildorado Repowering Tax Equity Holdco LLC, or WildoradoElbow Creek TE Holdco and Elbow Creek Repowering Tax Equity Holdco LLC, or Elbow Creek TE Holdco. The Company removed the related noncontrolling interest balance of $8 million and recorded the difference between the cash paid and the noncontrolling interest balance removed as a reduction to noncontrolling interests. The Company utilizes the HLBV method to determine the net income or loss allocated to tax equity noncontrolling interest.
AltaSpring Canyon TE Holdco — On June 30, 2015, the Company sold an economic interest in Alta TE Holdco to a financial institution in order to monetize certain cash and tax attributes, primarily PTCs. The financial institution, or Alta Investor, receives 99% of allocations of taxable income and other items until the flip point, which occurs when the Alta Investor obtains a specified return on its initial investment, at which time the allocations to the Alta Investor change to 5%. The Company receives 94.34% until the flip point, at which time the allocations to the Company of distributable cash will change to 97.12%, unless the flip point will not have occurred by a specified date, which would result in 100% of distributable cash allocated to the Alta Investor until the flip point occurs. Alta TE Holdco is a VIE and the Company is the primary beneficiary through its position as managing member, and therefore consolidates Alta TE Holdco, with the Alta Investor's interest shown as noncontrolling interest. The Company utilizes the HLBV method to determine the net income or loss allocated to the noncontrolling interest.projects.
Spring Canyon — The Company holds 90.1% of the Class B interests in Spring Canyon II, a 32 MW wind facility, and Spring Canyon III, a 28 MW wind facility, each located in Logan County, Colorado, and Invenergy Wind Global LLC owns 9.9% of the Class B interests. The projects are financed with a partnership flip tax-equity structure with a financial institution, who owns the Class A interests, to monetize certain cash and tax attributes, primarily PTCs. Until the flip point, the Class A member receives a variable percentage of cash distributions based on the projects’ production level during the prior year. After the flip point, cash distributions are allocated 5% to the Class A member and 95% to the Company and Invenergy. Spring Canyon is a VIE and the Company is the primary beneficiary through its position as managing member, and therefore consolidates Spring Canyon. The Class A member and Invenergy's interests are shown as noncontrolling interest. The Company utilizes the HLBV method to determine the net income or loss allocated to the Class A member. Net income or loss attributable to the Class B interests is allocated to Invenergy's noncontrolling interest based on its 9.9% ownership interest.
Note 6 — Fair Value of Financial Instruments
Fair Value Accounting under ASC 820
ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:
•Level 1—quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the measurement date.
•Level 2—inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.
•Level 3—unobservable inputs for the asset or liability only used when there is little, if any, market activity for the asset or liability at the measurement date.
In accordance with ASC 820, the Company determines the level in the fair value hierarchy within which each fair value measurement in its entirety falls, based on the lowest level input that is significant to the fair value measurement.
For cash and cash equivalents, restricted cash, accounts receivable — trade, accounts payable — trade, accounts payable — affiliates and accrued expenses and other current other 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, 2021 | | As of December 31, 2020 | | As of December 31, 2022 | | As of December 31, 2021 |
| | Carrying Amount | | Fair Value | | Carrying Amount | | Fair Value | | Carrying Amount | | Fair Value | | Carrying Amount | | Fair Value |
| | (In millions) | | (In millions) |
| | Liabilities: | Liabilities: | | Liabilities: | |
| Long-term debt, including current portion — affiliate | Long-term debt, including current portion — affiliate | $ | 1 | | | $ | 1 | | | $ | 1 | | | $ | 1 | | Long-term debt, including current portion — affiliate | $ | 2 | | | $ | 2 | | | $ | 1 | | | $ | 1 | |
Long-term debt, including current portion — external (a) | Long-term debt, including current portion — external (a) | 7,782 | | | 7,997 | | | 7,048 | | | 7,020 | | Long-term debt, including current portion — external (a) | 6,874 | | | 6,288 | | | 7,782 | | | 7,997 | |
(a) Excludes net debt issuance costs, which are recorded as a reduction to long-term debt on the Company'sCompany’s consolidated balance sheets.
The fair value of the Company'sCompany’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, 20212022 and 2020:2021:
| | | | | | | | | | | | | | | | | | | | | | | |
| As of December 31, 2021 | | As of December 31, 2020 |
| Level 2 | | Level 3 | | Level 2 | | Level 3 |
| | (In millions) |
| Long-term debt, including current portion | $ | 2,160 | | | $ | 5,838 | | | $ | 1,906 | | | $ | 5,115 | |
| | | | | | | |
| | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | |
| As of December 31, 2022 | | As of December 31, 2021 |
| Level 2 | | Level 3 | | Level 2 | | Level 3 |
| | (In millions) |
| Long-term debt, including current portion | $ | 1,836 | | | $ | 4,454 | | | $ | 2,160 | | | $ | 5,838 | |
| | | | | | | |
| | | | | | | |
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'sCompany’s consolidated balance sheets on a recurring basis and their level within the fair value hierarchy:
| | | As of December 31, 2021 | | As of December 31, 2020 | | As of December 31, 2022 | | As of December 31, 2021 |
| | Fair Value | | Fair Value (a) | | Fair Value | | | Fair Value (a) | | Fair Value | | Fair Value (a) | | Fair Value | | | Fair Value (a) |
| (In millions) | (In millions) | Level 2 | | Level 3 | | Level 2 | | | Level 3 | (In millions) | Level 2 (b) | | Level 3 | | Level 2 | | | Level 3 |
| Derivative assets | Derivative assets | | | | | | | | Derivative assets | | | | | | | |
| | Interest rate contracts | Interest rate contracts | $ | 6 | | | $ | — | | | $ | 1 | | | | $ | — | | Interest rate contracts | $ | 89 | | | $ | — | | | $ | 6 | | | | $ | — | |
Other financial instruments (b)(c) | Other financial instruments (b)(c) | — | | | 25 | | | — | | | | 29 | | Other financial instruments (b)(c) | — | | | 17 | | | — | | | | 25 | |
| Total assets | Total assets | $ | 6 | | | $ | 25 | | | $ | 1 | | | | $ | 29 | | Total assets | $ | 89 | | | $ | 17 | | | $ | 6 | | | | $ | 25 | |
| Derivative liabilities | Derivative liabilities | | | | | | | | Derivative liabilities | | | | | | | |
| Commodity contracts | Commodity contracts | $ | — | | | $ | 179 | | | $ | — | | | | $ | 44 | | Commodity contracts | $ | — | | | $ | 353 | | | $ | — | | | | $ | 179 | |
| Interest rate contracts | Interest rate contracts | 63 | | | — | | | 129 | | | | — | | Interest rate contracts | — | | | — | | | 63 | | | | — | |
| Total liabilities | Total liabilities | $ | 63 | | | $ | 179 | | | $ | 129 | | | | $ | 44 | | Total liabilities | $ | — | | | $ | 353 | | | $ | 63 | | | | $ | 179 | |
(a) There were no derivative assets classified as Level 1 or Level 3 and no liabilities classified as Level 1 as of December 31, 20212022 and December 31, 2020.2021.
(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., LIBOR and SOFR) and contractual terms to estimate fair value.
(c)Includes SREC contract acquired on November 2, 2020.contract.
The following table reconciles the beginning and ending balances for instruments that are recognized at fair value in the consolidated financial statements using significant unobservable inputs:
| | | | Year ended December 31, | | | Year ended December 31, |
| | | 2021 | | 2020 | | | 2022 | | 2021 |
| (In millions) | (In millions) | | | Fair Value Measurement Using Significant Unobservable Inputs (Level 3) | (In millions) | | | Fair Value Measurement Using Significant Unobservable Inputs (Level 3) |
| Beginning balance | Beginning balance | | | $ | (15) | | | $ | (9) | | Beginning balance | | | $ | (154) | | | $ | (15) | |
| Settlements | | Settlements | | | 61 | | | 60 | |
| Contracts acquired | | Contracts acquired | | | — | | | (52) | |
| Additions due to loss of NPNS exception | | Additions due to loss of NPNS exception | | | (22) | | | — | |
| Total losses for the period included in earnings | Total losses for the period included in earnings | | | (93) | | | — | | Total losses for the period included in earnings | | | (221) | | | (147) | |
| Contracts acquired | | | (52) | | | (6) | | |
| Settlements | | | 6 | | | — | | |
| Ending balance | Ending balance | | | $ | (154) | | | $ | (15) | | Ending balance | | | $ | (336) | | | $ | (154) | |
| Change in unrealized losses included in earnings for derivatives and other financial instruments held as of December 31, | Change in unrealized losses included in earnings for derivatives and other financial instruments held as of December 31, | | | $ | (93) | | | $ | 1 | | Change in unrealized losses included in earnings for derivatives and other financial instruments held as of December 31, | | | $ | (221) | | | $ | (147) | |
Derivative and Financial Instruments Fair Value Measurements
The Company'sCompany’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 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, 2021,2022, contracts valued with prices provided by models and other valuation techniques make up 74%100% of derivative liabilities and 100% of other financial instruments.
The Company’s significant positions classified as Level 3 include physical 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'sCompany’s Level 3 positions as of December 31, 2021:2022:
| | | December 31, 2021 | | December 31, 2022 |
| | Fair Value | | Input/Range | | Fair Value | | Input/Range |
| | Assets | Liabilities | Valuation Technique | Significant Unobservable Input | Low | High | Weighted Average | | Assets | Liabilities | Valuation Technique | Significant Unobservable Input | Low | High | Weighted Average |
| | (In millions) | | | (In millions) | |
| Commodity Contracts | Commodity Contracts | $ | — | | $ | (179) | | Discounted Cash Flow | Forward Market Price (per MWh) | $ | 13.93 | | $ | 56.06 | | $ | 27.46 | | Commodity Contracts | $ | — | | $ | (353) | | Discounted Cash Flow | Forward Market Price (per MWh) | $ | 21.25 | | $ | 100.66 | | $ | 41.09 | |
| Other Financial Instruments | Other Financial Instruments | 25 | | — | | Discounted Cash Flow | Forecast annual generation levels of certain DG solar facilities | 80,872 MWh | 129,913 MWh | 124,783 MWh | Other Financial Instruments | 17 | | — | | Discounted Cash Flow | Forecast annual generation levels of certain DG solar facilities | 58,539 MWh | 117,078 MWh | 112,897 MWh |
The following table provides the impact on the fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2021:2022:
| | | | | | | | | | | |
| Significant Observable Input | Position | Change In Input | Impact on Fair Value Measurement |
| Forward Market Price Power | Buy | Increase/(Decrease) | Higher/(Lower) |
| Forward Market Price Power | Sell | Increase/(Decrease) | Lower/(Higher) |
| 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, 2021,2022, the non-performance reserve was a $17$40 million gain recorded primarily to total operating revenues in the consolidated statement of operations.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'sCompany’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'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 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&E’s credit rating is below investment-grade.
Note 7 — 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'sCompany’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, 2021,2022, the Company had interest rate derivative instruments on non-recourse debt extending through 2031, 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 Commodities
As of December 31, 2021,2022, the Company had energy-related derivative instruments extending through 2033. At December 31, 2021,2022, 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'sCompany’s open derivative transactions broken out by commodity as of December 31, 20212022 and 2020:2021:
| | | | | | | | | | | | | | | | | |
| | | Total Volume |
| | | December 31, 2021 | | December 31, 2020 |
| Commodity | Units | | (In millions) |
| Natural Gas | MMBtu | | 2 | | | 1 | |
| Power | MWh | | (17) | | | (8) | |
| Interest | Dollars | | $ | 1,326 | | | $ | 1,600 | |
| | | | | | | | | | | | | | | | | |
| | | Total Volume |
| | | December 31, 2022 | | December 31, 2021 |
| Commodity | Units | | (In millions) |
| Natural Gas | MMBtu | | — | | | 2 | |
| Power | MWh | | (18) | | | (17) | |
| Interest | Dollars | | $ | 1,084 | | | $ | 1,326 | |
Fair Value of Derivative Instruments
The following table summarizes the fair value within the derivative instrument valuation on the consolidated balance sheets:
| | | | Fair Value | | Fair Value |
| | | Derivative Assets | | Derivative Liabilities | | Derivative Assets | | Derivative Liabilities |
| | December 31, 2021 | | December 31, 2020 | | December 31, 2021 | | December 31, 2020 | | December 31, 2022 | | December 31, 2021 | | December 31, 2022 | | December 31, 2021 |
| | (In millions) | | (In millions) |
| Derivatives Designated as Cash Flow Hedges: | Derivatives Designated as Cash Flow Hedges: | | | | | Derivatives Designated as Cash Flow Hedges: | | | | |
| Interest rate contracts current | Interest rate contracts current | $ | — | | | $ | — | | | $ | 5 | | | $ | 8 | | Interest rate contracts current | $ | 7 | | | $ | — | | | $ | — | | | $ | 5 | |
| Interest rate contracts long-term | Interest rate contracts long-term | 2 | | | — | | | 3 | | | 15 | | Interest rate contracts long-term | 18 | | | 2 | | | — | | | 3 | |
| Total Derivatives Designated as Cash Flow Hedges | Total Derivatives Designated as Cash Flow Hedges | $ | 2 | | | $ | — | | | $ | 8 | | | $ | 23 | | Total Derivatives Designated as Cash Flow Hedges | $ | 25 | | | $ | 2 | | | $ | — | | | $ | 8 | |
| Derivatives Not Designated as Cash Flow Hedges: | Derivatives Not Designated as Cash Flow Hedges: | | | | Derivatives Not Designated as Cash Flow Hedges: | | | |
| Interest rate contracts current | Interest rate contracts current | $ | — | | | $ | — | | | $ | 17 | | | $ | 25 | | Interest rate contracts current | $ | 19 | | | $ | — | | | $ | — | | | $ | 17 | |
| Interest rate contracts long-term | Interest rate contracts long-term | 4 | | | 1 | | | 38 | | | 81 | | Interest rate contracts long-term | 45 | | | 4 | | | — | | | 38 | |
| Commodity contracts current | Commodity contracts current | — | | | — | | | 24 | | | 5 | | Commodity contracts current | — | | | — | | | 50 | | | 24 | |
| Commodity contracts long-term | Commodity contracts long-term | — | | | — | | | 155 | | | 39 | | Commodity contracts long-term | — | | | — | | | 303 | | | 155 | |
| Total Derivatives Not Designated as Cash Flow Hedges | Total Derivatives Not Designated as Cash Flow Hedges | $ | 4 | | | $ | 1 | | | $ | 234 | | | $ | 150 | | Total Derivatives Not Designated as Cash Flow Hedges | $ | 64 | | | $ | 4 | | | $ | 353 | | | $ | 234 | |
| Total Derivatives | Total Derivatives | $ | 6 | | | $ | 1 | | | $ | 242 | | | $ | 173 | | Total Derivatives | $ | 89 | | | $ | 6 | | | $ | 353 | | | $ | 242 | |
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, 2022 and 2021, and 2020, there was nothe amount of outstanding collateral paid or received.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, 2021 | Gross Amounts of Recognized Assets/Liabilities | | Derivative Instruments | | Net Amount |
| Commodity contracts | (In millions) |
| | | | | |
| Derivative liabilities | $ | (179) | | | $ | — | | | $ | (179) | |
| Total commodity contracts | $ | (179) | | | $ | — | | | $ | (179) | |
| Interest rate contracts | | | | | |
| Derivative assets | $ | 6 | | | $ | (5) | | | $ | 1 | |
| Derivative liabilities | (63) | | | 5 | | | (58) | |
| Total interest rate contracts | $ | (57) | | | $ | — | | | $ | (57) | |
| Total derivative instruments | $ | (236) | | | $ | — | | | $ | (236) | |
| | | | | | | | | | | | | | | | | |
| | | | | |
| 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 |
| Commodity contracts | (In millions) |
| | | | | |
| Derivative liabilities | $ | (353) | | | $ | — | | | $ | (353) | |
| Total commodity contracts | $ | (353) | | | $ | — | | | $ | (353) | |
| Interest rate contracts | | | | | |
| Derivative assets | $ | 89 | | | $ | — | | | $ | 89 | |
| | | | | |
| Total interest rate contracts | $ | 89 | | | $ | — | | | $ | 89 | |
| Total derivative instruments | $ | (264) | | | $ | — | | | $ | (264) | |
| | | Gross Amounts Not Offset in the Statement of Financial Position | | Gross Amounts Not Offset in the Statement of Financial Position |
| As of December 31, 2020 | Gross Amounts of Recognized Assets/Liabilities | | Derivative Instruments | | Net Amount | |
| As of December 31, 2021 | | As of December 31, 2021 | Gross Amounts of Recognized Assets/Liabilities | | Derivative Instruments | | Net Amount |
| Commodity contracts | Commodity contracts | (In millions) | Commodity contracts | (In millions) |
| | Derivative liabilities | Derivative liabilities | $ | (44) | | | $ | — | | | $ | (44) | | Derivative liabilities | $ | (179) | | | $ | — | | | $ | (179) | |
| Total commodity contracts | Total commodity contracts | $ | (44) | | | $ | — | | | $ | (44) | | Total commodity contracts | $ | (179) | | | $ | — | | | $ | (179) | |
| Interest rate contracts | Interest rate contracts | | | | | | Interest rate contracts | | | | | |
| Derivative assets | Derivative assets | $ | 1 | | | $ | — | | | $ | 1 | | Derivative assets | $ | 6 | | | $ | (5) | | | $ | 1 | |
| Derivative liabilities | Derivative liabilities | (129) | | | — | | | (129) | | Derivative liabilities | (63) | | | 5 | | | (58) | |
| Total interest rate contracts | Total interest rate contracts | $ | (128) | | | $ | — | | | $ | (128) | | Total interest rate contracts | $ | (57) | | | $ | — | | | $ | (57) | |
| Total derivative instruments | Total derivative instruments | $ | (172) | | | $ | — | | | $ | (172) | | Total derivative instruments | $ | (236) | | | $ | — | | | $ | (236) | |
Accumulated Other Comprehensive LossIncome (Loss)
The following table summarizes the effects on the Company’s accumulated OCLOCI (OCL) balance attributable to interest rate swaps designated as cash flow hedge derivatives:
| | | | | | | | | | | | | | | | | |
| Year ended December 31, |
| 2021 | | 2020 | | 2019 |
| (In millions) |
| Accumulated OCL beginning balance | $ | (35) | | | $ | (37) | | | $ | (45) | |
| | | | | |
| Reclassified from accumulated OCL to income due to realization of previously deferred amounts | 11 | | | 11 | | | 22 | |
| Mark-to-market of cash flow hedge accounting contracts | 11 | | | (9) | | | (14) | |
| Accumulated OCL ending balance | $ | (13) | | | $ | (35) | | | $ | (37) | |
| Accumulated OCL attributable to noncontrolling interests | — | | | (2) | | | — | |
| Accumulated OCL attributable to Clearway Energy LLC | $ | (13) | | | $ | (33) | | | $ | (37) | |
| Losses expected to be realized from OCL during the next 12 months | $ | (9) | | | 0 | | 0 |
| | | | | | | | | | | | | | | | | |
| Year ended December 31, |
| 2022 | | 2021 | | 2020 |
| (In millions) |
| Accumulated OCI (OCL) beginning balance | $ | (13) | | | $ | (35) | | | $ | (37) | |
| | | | | |
| Reclassified from accumulated OCI/OCL to income due to realization of previously deferred amounts | 5 | | | 11 | | | 11 | |
| Capistrano Wind Portfolio Acquisition | 7 | | | — | | | — | |
| Mark-to-market of cash flow hedge accounting contracts | 28 | | | 11 | | | (9) | |
| Accumulated OCI (OCL) ending balance | $ | 27 | | | $ | (13) | | | $ | (35) | |
| Accumulated OCI (OCL) attributable to noncontrolling interests | 6 | | | — | | | (2) | |
| Accumulated OCI (OCL) attributable to Clearway Energy LLC | $ | 21 | | | $ | (13) | | | $ | (33) | |
| Income expected to be realized from OCI during the next 12 months | $ | 5 | | | | | |
Amounts reclassified from accumulated OCI/OCL into income are recorded to interest expense.
Impact of Derivative Instruments on the Consolidated Statements of OperationsIncome
Mark-to-market gains and lossesgains/(losses) related to the Company'sCompany’s derivatives are recorded in the consolidated statements of operationsincome as follows:
| | | | | | | | | | | | | | | | | |
| Year ended December 31, |
| 2021 | | 2020 | | 2019 |
| (In millions) |
| Interest Rate Contracts (Mark-to-market interest expense) | $ | 53 | | | $ | (38) | | | $ | (65) | |
Commodity Contracts (Mark-to-market for economic hedging activities) (a) | (83) | | | (4) | | | (9) | |
| | | | | | | | | | | | | | | | | |
| Year ended December 31, |
| 2022 | | 2021 | | 2020 |
| (In millions) |
| Interest Rate Contracts (Interest expense) | $ | 100 | | | $ | 53 | | | $ | (38) | |
Commodity Contracts (Operating revenue) (a) | (174) | | | (83) | | | (4) | |
(a) Relates to long-term commodity contracts at Elbow Creek, Wind Project LLC, or Elbow Creek, Mesquite Star, Mt. Storm, Langford and Mesquite SkySky. During the year ended December 31, 2022, the commodity contract for Langford, which previously met the NPNS exception, no longer qualified for NPNS treatment and, gains or losses are recognized inaccordingly, is accounted for as a derivative and marked to fair value through operating revenues.
APrior to the Thermal Disposition, which is further described in Note 3, Acquisitions and Dispositions, a portion of the Company’s derivative commodity contracts relateswere related to its Thermal Business for the purchase of fuel/electricity commodities based on the forecasted usage of the thermal district energy centers. Realized gains and losses on these contracts arewere reflected in the fuel costs that arewere permitted to be billed to customers through the related customer contracts or tariffs and, accordingly, no gains or losses arewere reflected in the consolidated statements of operationsincome for these contracts.contracts through the period that the Company owned the Thermal Business.
See Note 6, Fair Value of Financial Instruments, for a discussion regarding concentration of credit risk.
Note 8 — Intangible Assets
Intangible Assets — The Company'sCompany’s intangible assets as of December 31, 20212022 and 20202021 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, and 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.
•Customer relationships — Established with the acquisition of Energy Center Omaha and Energy Center Phoenix, these intangibles represent the fair value at the acquisition date of the businesses' customer base. The customer relationships related to Energy Center Omaha are amortized as a reduction to operating revenue, which approximates the expected discounted future net cash flows by year. These intangible assets arewere included in the Thermal Business and were reclassified toclassified as held for sale during the fourth quarter ofat December 31, 2021. The Thermal Business was sold on May 1, 2022.
•Customer contracts — Established with the acquisition of Energy Center Phoenix, these intangibles represent the fair value at the acquisition date of contracts that primarily provide chilled water, steam and electricity to its customers. These contracts are amortized to revenues based on expected volumes. These intangible assets arewere included in the Thermal Business and were reclassified toclassified as held for sale during the fourth quarter ofat December 31, 2021. The Thermal Business was sold on May 1, 2022.
•Emission Allowances — These intangibles primarily consist of SO2 and NOx emission allowances established with the El Segundo, Walnut Creek and Carlsbad Energy Center acquisitions. These emission allowances are held-for-use and are amortized to cost of operations, with NOx allowances amortized on a straight-line basis and SO2 allowances amortized based on units of production.
•Other — Consists of a) the acquisition date fair value of the contractual rights to a ground lease for South Trent and to utilize certain interconnection facilities for Blythe as well as land rights acquired in connection with the acquisition of Elbow Creek and Langford Wind; b) development rights related to certain solar business acquisitions; c) RECs acquired in connection with the acquisition of the Utah Solar Portfolio; and d) 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, 2021 | PPAs | | Leasehold Rights | | Customer
Relationships | | Customer Contracts | | Emission Allowances | | | Other | | Total | |
| Year ended December 31, 2022 | | Year ended December 31, 2022 | PPAs | | Leasehold Rights | | Emission Allowances | | | Other | | Total |
| (In millions) | (In millions) | | | | (In millions) | | | |
| January 1, 2021 | $ | 1,661 | | | $ | 86 | | | $ | 66 | | | $ | 15 | | | $ | 17 | | | | $ | 12 | | | $ | 1,857 | | |
| January 1, 2022 | | January 1, 2022 | $ | 2,985 | | | $ | 86 | | | $ | 17 | | | | $ | 16 | | | $ | 3,104 | |
Acquisitions (a) | | Acquisitions (a) | 336 | | | — | | | — | | | | — | | | 336 | |
| Other | | Other | — | | | — | | | — | | | | 2 | | | 2 | |
| Acquisitions (a) | 1,324 | | | — | | | — | | | — | | | — | | | | 4 | | | 1,328 | | |
Reclassified to held for sale (b) | — | | | — | | | (66) | | | (15) | | | — | | | | — | | | (81) | | |
| December 31, 2021 | 2,985 | | | 86 | | | — | | | — | | | 17 | | | | 16 | | | 3,104 | | |
| December 31, 2022 | | December 31, 2022 | 3,321 | | | 86 | | | 17 | | | | 18 | | | 3,442 | |
| Less accumulated amortization | Less accumulated amortization | (566) | | | (30) | | | — | | | — | | | (3) | | | | (6) | | | (605) | | Less accumulated amortization | (833) | | | (34) | | | (4) | | | | (6) | | | (877) | |
| Net carrying amount | Net carrying amount | $ | 2,419 | | | $ | 56 | | | $ | — | | | $ | — | | | $ | 14 | | | | $ | 10 | | | $ | 2,499 | | Net carrying amount | $ | 2,488 | | | $ | 52 | | | $ | 13 | | | | $ | 12 | | | $ | 2,565 | |
(a) The weighted average life of acquired intangibles was 10 years for PPAs.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Year ended December 31, 2021 | PPAs | | Leasehold Rights | | Customer Relationships | | Customer Contracts | | Emission
Allowances | | | | Other | | Total |
| (In millions) | | | | | | | | | | | | | | | |
| January 1, 2021 | $ | 1,661 | | | $ | 86 | | | $ | 66 | | | $ | 15 | | | $ | 17 | | | | | $ | 12 | | | $ | 1,857 | |
Acquisitions (a) | 1,324 | | | — | | | — | | | — | | | — | | | | | 4 | | | 1,328 | |
Reclassified to held for sale (b) | — | | | — | | | (66) | | | (15) | | | — | | | | | — | | | (81) | |
| December 31, 2021 | 2,985 | | | 86 | | | — | | | — | | | 17 | | | | | 16 | | | 3,104 | |
| Less accumulated amortization | (566) | | | (30) | | | — | | | — | | | (3) | | | | | (6) | | | (605) | |
| Net carrying amount | $ | 2,419 | | | $ | 56 | | | $ | — | | | $ | — | | | $ | 14 | | | | | $ | 10 | | | $ | 2,499 | |
(a) The weighted average life of acquired intangibles was 17 years for PPAs, 15 years for RECs and 15 years for favorable leases.
(b) Thermal Business intangible assets were reclassified toclassified as held for sale duringat December 31, 2021, and the fourth quarter of 2021.Thermal Business was subsequently sold on May 1, 2022.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Year ended December 31, 2020 | PPAs | | Leasehold Rights | | Customer Relationships | | Customer Contracts | | Emission
Allowances | | | | Other | | Total |
| (In millions) | | | | | | | | | | | | | | | |
| January 1, 2020 | $ | 1,630 | | | $ | 86 | | | $ | 66 | | | $ | 15 | | | $ | 17 | | | | | $ | 8 | | | $ | 1,822 | |
| Consolidation of DGPV Holdco Entities | 23 | | | — | | | — | | | — | | | — | | | | | — | | | 23 | |
| Other | 8 | | | — | | | — | | | — | | | — | | | | | 4 | | | 12 | |
| December 31, 2020 | 1,661 | | | 86 | | | 66 | | | 15 | | | 17 | | | | | 12 | | | 1,857 | |
| Less accumulated amortization | (431) | | | (26) | | | (11) | | | (11) | | | (3) | | | | | (5) | | | (487) | |
| Net carrying amount | $ | 1,230 | | | $ | 60 | | | $ | 55 | | | $ | 4 | | | $ | 14 | | | | | $ | 7 | | | $ | 1,370 | |
The Company recorded amortization expense of $143$174 million during the year ended December 31, 2022, $143 million for the year ended December 31, 2021 and $91 million for the year ended December 31, 2020 and $732020. Of these amounts, $168 million for the year ended December 31, 2019. Of these amounts,2022, $135 million for the year ended December 31, 2021 and $88 million for the year ended December 31, 2020, and $72 million for the year ended December 31, 2019, 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 operations.income. The Company estimates the future amortization expense for its intangibles for the next five years as follows:
| | | (In millions) | | | (In millions) | |
| | 2022 | $ | 158 | | | |
| 2023 | 2023 | 155 | | | 2023 | $ | 182 | | |
| 2024 | 2024 | 153 | | | 2024 | 180 | | |
| 2025 | 2025 | 153 | | | 2025 | 180 | | |
| 2026 | 2026 | 153 | | | 2026 | 180 | | |
| 2027 | | 2027 | 180 | | |
Note 9 — Asset Impairments
20212022 Impairment Losses
During the fourth quarter of 20212022, 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 annual budget process coincides with the Company's annual impairment analysis of long-lived assets. The impairment analysis reviews certain qualitative factors as well as the fair valueresults of the facilities againstlong-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 $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.
2020 Impairment Losses
During the fourth quarter of 2020 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 annual budget process coincides with the Company's annual impairment analysis of long-lived assets. The impairment analysis reviews certain qualitative factors as well as the fair value of the facilities against its carrying value to determine if impairment indicators are present. 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 $24 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.
Additionally, during the fourth quarter of 2020, as the Company updated its estimated cash flows in connection with the preparation and review of the Company'sCompany’s annual budget, the Company determined that there was a significant decrease in the estimated future cash flows for its equity method investment in San Juan Mesa, a facility in the Renewables segment located in Elida, New Mexico. The decrease in the forecasted cash flows which was primarily driven by a decline in forecasted revenue in future merchant periods, was significant enough to be considered an indication of a decline in value of the investment that was not temporary. The Company concluded there was an other-than-temporary impairment of its investment and recorded an impairment loss of $8 million to reflect the investment at fair market value. The resulting fair value is a Level 3 fair value measurement.
2019 Impairment Losses
The Company recorded an impairment loss of $19 million related to a facility in the Thermal segment during the second quarter of 2019. The impairment was triggered by a potential sale negotiation with a third-party, which resulted in signing the purchase and sale agreement in September 2019, as further described in Note 3, Acquisitions and Dispositions. The fair value of the facility was determined using an income approach by applying a discounted cash flow methodology to the long-term budgets for each respective plant. The income approach utilized estimates of discounted future cash flows, which were Level 3 fair value measurement and include key inputs, such as forecasted power prices, operations and maintenance expense, and discount rates. The Company measured the impairment loss as the difference between the carrying amount and the fair value of the assets.
Additionally, during the fourth quarter of 2019, as a result of the preparation and review of its annual budget and assessment of long-term merchant power prices, the Company updated its estimated future cash flows and determined that the future cash flows for several wind projects within the Renewables segment no longer supported the recoverability of the related long-lived asset. The annual budget process coincides with the Company's annual impairment analysis of long-lived assets. The impairment analysis reviewed certain qualitative factors as well as the fair value of the facilities against its carrying value to determine if impairment indicators are present. As such, the Company recorded an impairment loss of $14 million 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.
Note 10 — Long-term Debt
The Company'sCompany’s borrowings, including short-term and long-term portions consisted of the following:
| | | December 31, 2021 | | December 31, 2020 | | Interest rate % (a) | | Letters of Credit Outstanding at December 31, 2021 | | December 31, 2022 | | December 31, 2021 | | Interest rate % (a)(b) | | Letters of Credit Outstanding at December 31, 2022 |
| | (In millions, except rates) | | | | (In millions, except rates) | | |
| | Intercompany Note with Clearway Energy, Inc. | Intercompany Note with Clearway Energy, Inc. | $ | 1 | | | $ | 1 | | | 1.490 | | | Intercompany Note with Clearway Energy, Inc. | $ | 2 | | | $ | 1 | | | 4.550 | | |
| 2025 Senior Notes | — | | | 600 | | | 5.750 | | | |
| 2026 Senior Notes | — | | | 350 | | | 5.000 | | | |
| | 2028 Senior Notes | 2028 Senior Notes | 850 | | | 850 | | | 4.750 | | | 2028 Senior Notes | 850 | | | 850 | | | 4.750 | | |
| 2031 Senior Notes | 2031 Senior Notes | 925 | | | — | | | 3.750 | | 2031 Senior Notes | 925 | | | 925 | | | 3.750 | |
| 2032 Senior Notes | 2032 Senior Notes | 350 | | | — | | | 3.750 | | 2032 Senior Notes | 350 | | | 350 | | | 3.750 | |
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 (b)(c) | Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 (b)(c) | 245 | | | — | | | 1.750 | | $ | 83 | | Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 (b)(c) | — | | | 245 | | | 1.750 | | $ | 125 | |
Bridge Loan, due 2022 (c) | Bridge Loan, due 2022 (c) | 335 | | | — | | | S+1.000 | | Bridge Loan, due 2022 (c) | — | | | 335 | | | S+1.250 | |
| Project-level debt: | | |
| Non-recourse project-level debt: | | Non-recourse project-level debt: | |
| Agua Caliente Solar LLC, due 2037 | Agua Caliente Solar LLC, due 2037 | 684 | | | — | | | 2.395 - 3.633 | | 45 | | Agua Caliente Solar LLC, due 2037 | 649 | | | 684 | | | 2.395-3.633 | | 45 | |
| Alta Wind Asset Management LLC, due 2031 | Alta Wind Asset Management LLC, due 2031 | 13 | | | 14 | | | L+2.625 | | — | | Alta Wind Asset Management LLC, due 2031 | 12 | | | 13 | | | L+2.625 | | — | |
| Alta Wind I-V lease financing arrangements, due 2034 and 2035 | Alta Wind I-V lease financing arrangements, due 2034 and 2035 | 756 | | | 800 | | | 5.696 - 7.015 | | 34 | | Alta Wind I-V lease financing arrangements, due 2034 and 2035 | 709 | | | 756 | | | 5.696-7.015 | | 23 | |
| Alta Wind Realty Investments LLC, due 2031 | Alta Wind Realty Investments LLC, due 2031 | 24 | | | 25 | | | 7.000 | | — | | Alta Wind Realty Investments LLC, due 2031 | 22 | | | 24 | | | 7.000 | | — | |
| Borrego, due 2024 and 2038 | Borrego, due 2024 and 2038 | 54 | | | 57 | | | Various | | — | | Borrego, due 2024 and 2038 | 51 | | | 54 | | | Various | | — | |
| Buckthorn Solar, due 2025 | Buckthorn Solar, due 2025 | 123 | | | 126 | | | L+1.750 | | 21 | | Buckthorn Solar, due 2025 | 119 | | | 123 | | | L+1.750 | | 21 | |
| Capistrano Wind Portfolio, due 2029 and 2031 | | Capistrano Wind Portfolio, due 2029 and 2031 | 156 | | | — | | | L+2.000 | | 36 | |
| Carlsbad Energy Holdings LLC, due 2027 | Carlsbad Energy Holdings LLC, due 2027 | 136 | | | 156 | | | L+1.625 | | 62 | | Carlsbad Energy Holdings LLC, due 2027 | 115 | | | 136 | | | L+1.750 | | 63 | |
| Carlsbad Energy Holdings LLC, due 2038 | Carlsbad Energy Holdings LLC, due 2038 | 407 | | | 407 | | | 4.120 | | — | | Carlsbad Energy Holdings LLC, due 2038 | 407 | | | 407 | | | 4.120 | | — | |
| Carlsbad Holdco, due 2038 | 205 | | | 210 | | | 4.210 | | | 6 | | |
| Carlsbad Holdco, LLC, due 2038 | | Carlsbad Holdco, LLC, due 2038 | 197 | | | 205 | | | 4.210 | | 5 | |
| CVSR, due 2037 | CVSR, due 2037 | 652 | | | 675 | | | 2.339 - 3.775 | | — | | CVSR, due 2037 | 627 | | | 652 | | | 2.339-3.775 | | — | |
| CVSR Holdco Notes, due 2037 | CVSR Holdco Notes, due 2037 | 169 | | | 176 | | | 4.680 | | | 13 | | CVSR Holdco Notes, due 2037 | 160 | | | 169 | | | 4.680 | | 12 | |
| DG-CS Master Borrower LLC, due 2040 | DG-CS Master Borrower LLC, due 2040 | 441 | | | 467 | | | 3.510 | | | 30 | | DG-CS Master Borrower LLC, due 2040 | 413 | | | 441 | | | 3.510 | | 30 | |
Duquesne, due 2059 (d) | — | | | 95 | | | 4.620 | | | — | | |
| | El Segundo Energy Center, due 2023 | El Segundo Energy Center, due 2023 | 193 | | | 250 | | | L+1.875 - L+2.500 | | 138 | | El Segundo Energy Center, due 2023 | — | | | 193 | | | L+1.875-2.500 | | 80 | |
Energy Center Minneapolis Series D, E, F, G, H Notes, due 2025-2037 (d) | — | | | 327 | | | Various | | — | | |
| | Kawailoa Solar Portfolio LLC, due 2026 | Kawailoa Solar Portfolio LLC, due 2026 | 78 | | | 81 | | | L+1.375 | | 14 | | Kawailoa Solar Portfolio LLC, due 2026 | — | | | 78 | | | L+1.375 | | — | |
| Laredo Ridge, due 2028 | Laredo Ridge, due 2028 | 72 | | | 78 | | | L+2.125 | | 3 | | Laredo Ridge, due 2028 | — | | | 72 | | | L+2.125 | | — | |
| Marsh Landing, due 2023 | Marsh Landing, due 2023 | 84 | | | 146 | | | L+2.375 | | 46 | | Marsh Landing, due 2023 | 19 | | | 84 | | | L+2.375 | | 45 | |
| Mililani I, due 2027 | | Mililani I, due 2027 | 47 | | | — | | | L+1.500 | | 6 | |
| NIMH Solar, due 2024 | NIMH Solar, due 2024 | 176 | | | 191 | | | L+2.000 | | 10 | | NIMH Solar, due 2024 | 163 | | | 176 | | | L+2.000 | | 10 | |
| Oahu Solar Holdings LLC, due 2026 | Oahu Solar Holdings LLC, due 2026 | 86 | | | 89 | | | L+1.375 | | 10 | | Oahu Solar Holdings LLC, due 2026 | 83 | | | 86 | | | L+1.375 | | 9 | |
| | Rosie Class B LLC, due 2027 | Rosie Class B LLC, due 2027 | 78 | | | 80 | | | L+1.750 | | 17 | | Rosie Class B LLC, due 2027 | 76 | | | 78 | | | L+1.750 | | 17 | |
| Tapestry, due 2031 | 85 | | | 143 | | | L+1.375 | | 12 | | |
| Tapestry Wind LLC, due 2031 | | Tapestry Wind LLC, due 2031 | — | | | 85 | | | L+1.375 | | — | |
| Utah Solar Holdings, due 2036 | Utah Solar Holdings, due 2036 | 273 | | | 290 | | | 3.590 | | | 10 | | Utah Solar Holdings, due 2036 | 257 | | | 273 | | | 3.590 | | | 9 | |
Viento Funding II, LLC, due 2023 and 2029 (d) | | Viento Funding II, LLC, due 2023 and 2029 (d) | 184 | | | 29 | | | S+1.475 | | 26 | |
| Waiawa, due 2023 and 2028 | | Waiawa, due 2023 and 2028 | 97 | | | — | | | L+1.000-1.250 | | 10 | |
| Walnut Creek, due 2023 | Walnut Creek, due 2023 | 74 | | | 126 | | | L+1.750 | | 116 | | Walnut Creek, due 2023 | 19 | | | 74 | | | L+1.875 | | 74 | |
| WCEP Holdings, LLC, due 2023 | WCEP Holdings, LLC, due 2023 | 30 | | | 35 | | | L+3.000 | | — | | WCEP Holdings, LLC, due 2023 | 26 | | | 30 | | | L+3.000 | | — | |
| Other | Other | 180 | | | 199 | | | Various | | 201 | | Other | 137 | | | 151 | | | Various | | 200 | |
| Subtotal project-level debt | 5,073 | | | 5,243 | | | |
| Subtotal non-recourse project-level debt | | Subtotal non-recourse project-level debt | 4,745 | | | 5,073 | | |
| Total debt | Total debt | 7,779 | | | 7,044 | | | Total debt | 6,872 | | | 7,779 | | |
| Less current maturities | Less current maturities | (773) | | | (385) | | | Less current maturities | (324) | | | (773) | | |
| Less net debt issuance costs | Less net debt issuance costs | (71) | | | (79) | | | Less net debt issuance costs | (61) | | | (71) | | |
Add premiums (e) | Add premiums (e) | 4 | | | 5 | | | Add premiums (e) | 4 | | | 4 | | |
| Total long-term debt | Total long-term debt | $ | 6,939 | | | $ | 6,585 | | | Total long-term debt | $ | 6,491 | | | $ | 6,939 | | |
(a) As of December 31, 2021,2022, L+ equals 3 month LIBOR plus x%, except Clearway Energy Operating LLC Revolving Credit Facility,Marsh Landing, due 2023, Marsh Landing,Waiawa, due 2023, and Walnut Creek, due 2023, where L+ equals 1 month LIBOR plus x%.
(b)S+ equals SOFR, plus x%
(c) Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement
(c) S+ equals SOFR, plus x%
(d) Thermal Business long-termLaredo Ridge, due 2028; Tapestry Wind LLC, due 2031; and Viento Funding II, LLC, due 2023 project-level debt reclassified to held for salewere repaid on March 16, 2022 totaling $186 million and was replaced with $190 million in the fourth quarter of 2021new project-level debt under Viento Funding II, LLC that was obtained on March 16, 2022 and is due in 2029, as discussed further below.
(e) 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, 2021,2022, the Company was in compliance with all of the required principal, interest, sinking fund and redemption covenants.
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 providesprovided for a senior secured term loan facility in an aggregate principal amount of $335 million. Borrowings under the term loan facility bear interest, at Clearway Energy Operating LLC’s option, at a rate per annum equal to either (a) term SOFR, plus a SOFR adjustment and a margin equal to 1.00% during the period from December 1, 2021 through May 31, 2022, and 1.25% thereafter or (b) a base rate plus a margin equal to 0.00% during the period from December 1, 2021 through May 31, 2022, and 0.25% thereafter. The Bridge Loan Agreement will mature no later than November 29, 2022 and the Company intends to use the proceeds from the Thermal Disposition to repay the outstanding principal balance of the term loans under the Bridge Loan Agreement. Borrowings under the Bridge Loan Agreement are guaranteed by Clearway Energy LLC and certain subsidiaries of Clearway Operating LLC, other than subsidiaries that are excluded project companies, and are secured by substantially all of the assets of Clearway Energy Operating LLC and its guarantor subsidiaries. The borrowings under the term loan facility were used to acquire the Utah Solar Portfolio on December 1, 2021, as further described in Note 3, Acquisitions and Dispositions.
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 as further described in Note 3, Acquisitions and Dispositions.
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility
On November 30, 2021, Clearway Energy Operating LLC entered into the Sixth Amendment to Amended and Restated Credit Agreement, which amended the Company’s revolving credit facility to provide for an increase of the maximum permitted Borrower Leverage Ratio (as defined in the credit agreement governing the Company’s revolving credit facility) to 6.00 to 1.00 during the period commencing onfrom November 30, 2021 and ending on the date which is the earliest of (i) two business days following the consummation of the Thermal Disposition, (ii) 120 days following the termination or expiration of the agreement entered into with KKR to sell the Thermal Business and (iii) the maturity date of the Bridge Loan Agreement, or the Leverage Period Termination Date.through May 2, 2022. The Sixth Amendment also (i) permits the incurrence of the term loan facility under the Bridge Loan Agreement, (ii) permits the incurrence of hedging obligations, subject to certain conditions, and provides for a $40 million basket for cash collateral which may be provided to secure hedging obligations (iii) permits the prepayment of unsecured, junior or subordinated indebtedness at any time following the Leverage Period Termination Date,May 3, 2022, subject to certain conditions, including that, after giving effect to such payment, the Borrower Leverage Ratio would not be greater than 5.50 to 1.00 and the Borrower Interest Coverage Ratio (as defined in the credit agreement governing the Company'sCompany’s revolving credit facility) would not be less than 1.75 to 1.00 and (iv) implements certain other technical modifications.
As of December 31, 2021,2022, the Company had $245 million inno outstanding borrowings under the revolving credit facility and $83$125 million in letters of credit outstanding. During the year ended December 31, 2021,2022, the Company borrowed $622$80 million under the revolving credit facility and subsequently repaid $377$325 million, $305 million of which was repaid on May 3, 2022, utilizing cash on hand andthe proceeds received from the issuanceThermal Disposition. The facility will continue to be used for general corporate purposes including financing of the 2031 Senior Notes, as described below.future acquisitions and posting letters of credit.
2032 Senior Notes
On October 1, 2021, Clearway Energy Operating LLC completed the sale of $350 million of senior unsecured notes due 2032, or the 2032 Senior Notes. The 2032 Senior Notes bear interest at 3.750% and mature on January 15, 2032. Interest on the 2032 Senior Notes is payable semi-annually on January 15 and July 15 of each year. The 2032 Senior Notes are unsecured obligations of Clearway Energy Operating LLC and are guaranteed by Clearway Energy LLC and by certain of Clearway Energy Operating LLC'sLLC’s wholly-owned current and future subsidiaries. The net proceeds from the 2032 Senior Notes were used, together with existing corporate liquidity, to repurchase the 2026 Senior Notes, as described below.
2026 Senior Notes Tender Offer and Redemption
In October 2021, the Company repurchased and redeemed an aggregate principal amount of $350 million of the 2026 Senior Notes, through the cash tender offer announced on September 24, 2021 and the redemption of the remaining principal amount of $227 million on October 25, 2021. The 2026 Senior Notes repurchased and redeemed in October 2021 were effectuated at a premium of approximately 103% for total consideration of $359 million and, as a result, the Company recorded a loss on extinguishment in the amount of $9 million. The Company recorded an additional $3 million loss on extinguishment to write off the remaining unamortized deferred financing fees related to the 2026 Senior Notes.
2031 Senior Notes
On March 9, 2021, Clearway Energy Operating LLC completed the sale of $925 million of senior unsecured notes due 2031, or the 2031 Senior Notes. The 2031 Senior Notes bear interest at 3.750% and mature on February 15, 2031. Interest on the 2031 Senior Notes is payable semi-annually on February 15 and August 15 of each year. The 2031 Senior Notes are unsecured obligations of Clearway Energy Operating LLC and are guaranteed by Clearway Energy LLC and by certain of Clearway Energy Operating LLC'sLLC’s wholly-owned current and future subsidiaries. The net proceeds from the 2031 Senior Notes were used to repurchase the 2025 Senior Notes, as described below, as well as to repay amounts outstanding under the Company’s revolving credit facility and for general corporate purposes.
2025 Senior Notes Tender Offer and Redemption
In March 2021, the Company repurchased and redeemed an aggregate principal amount of $600 million of the 2025 Senior Notes, through the cash tender offer announced on March 2, 2021 and the redemption of the remaining principal amount of $183 million on March 17, 2021. The 2025 Senior Notes repurchased and redeemed in March 2021 were effectuated at a premium of approximately 106% for total consideration of $636 million and, as a result, the Company recorded a loss on extinguishment in the amount of $36 million. The Company recorded an additional $5 million loss on extinguishment to write off the remaining unamortized deferred financing fees related to the 2025 Senior Notes.
2020 Convertible NotesProject-level Debt
The 2020 Convertible Notes matured on June 1, 2020 andEl Segundo Energy Center
On December 15, 2022, the Company repaid the outstanding principalproject-level debt of El Segundo Energy Center in the amount of $45approximately $130 million, utilizing cash on hand. The project-level debt had an original maturity of August 2023.
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 that converts to a term loan upon the project reaching substantial completion, a $55 milliontax equity bridge loan and a $26 million sponsor equity bridge loan. 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. The tax equity bridge loan will be repaid with the final proceeds from the tax equity investor that will be received upon Waiawa reaching substantial completion, which is expected to occur in the first half of 2023. Subsequent to the Waiawa acquisition, the Company borrowed an additional $20 million in construction loans. As of December 31, 2022, the Company had $42 million in outstanding construction loans in addition to the $55 million tax equity bridge loan referenced above.
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. The non-recourse project-level debt bears interest at a rate of LIBOR plus an applicable margin, which is currently 2.00% per annum, and maturities range from September 30, 2029 to July 14, 2031.
Mililani I
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 that converts to a term loan upon the project reaching substantial completion, a $60 million tax equity bridge loan and a $27 million sponsor equity bridge loan. 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 Mililani I acquisition, the Company had borrowed an additional $32 million in construction loans that was converted to a term loan in the amount of $48 million. The repaymentAs of December 31, 2022, the Company had a $47 million term loan outstanding, as $1 million was funded bypaid in December 2022.
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 the 2028 Senior Notes.
2028 Senior Notes
On May 21, 2020, the Company completed the issuance of an additional $250a $190 million in aggregate principal amount of its 4.750% Senior Notes due 2028. The 2028 Senior Notes bear interest at 4.75% and mature on March 15, 2028. Interest on the 2028 Senior Notes is payable semi-annually on March 15 and September 15 of each year. The 2028 Senior Notes are unsecured obligations of Clearway Energy Operating, LLC and are guaranteed by Clearway Energy, LLC and by certain of Clearway Energy Operating LLC’s wholly-owned current and future subsidiaries. The notes were issued at a price of 102% of par plus accrued interest from December 11, 2019. The net proceeds were utilized to repay the $45 million outstanding principal amount of the Company's 2020 Convertible Notes on June 1, 2020,term loan as well as to repay amounts outstanding under$35 million in letters of credit, supported by the Company’s revolving credit facilityinterests in the Elkhorn Ridge, Laredo Ridge, San Juan Mesa and for general corporate purposes.
2024 Senior Notes Redemption
On January 3, 2020,Taloga wind projects. The term loan bears annual interest at a rate of SOFR plus a spread of 0.10% and an applicable margin, which is 1.375% per annum through the Company redeemedfourth anniversary of the $88 million aggregate principalterm loan and 1.50% per annum thereafter through the maturity date of March 16, 2029. The proceeds from the term loan were used to pay off the existing debt in the amount of the 2024 Senior Notes that remained outstanding following the Company's tender offer for the 2024 Senior Notes in December 2019.$186 million related to Laredo Ridge, Tapestry Wind LLC and Viento Funding II, LLC and to pay related financing costs. The redemption was effectuated at a premium of 102.7%for a total consideration of $90 million and as a result, the Company recorded a loss on debt extinguishment in the amount of $3$2 million which also included the write off of previously deferred financing fees related to the 2024 Senior Notes.expense unamortized debt issuance costs.
Intercompany Note with Clearway Energy, Inc.
On February 18, 2020, the Company entered into an intercompany demand promissory note with Clearway Energy, Inc. in the principal amount of $3 million. The unpaid principal amount bears interest at a rate equal to the short-term applicable federal rate, which is payable on the last day of each quarter, or at other times as agreed upon by the Company and Clearway Energy, Inc. As of December 31, 2021, $1 million was outstanding.
Project level Debt
Agua Caliente Solar LLC
As part of the acquisition of Agua Caliente Borrower 1 LLC and the consolidation of Agua Caliente, as further described in Note 3, Acquisitions and Dispositions, the Company consolidated non-recourse debt of $716 million related to Agua Caliente Solar, LLC on February 3, 2021. The debt consists of a credit agreement with the Federal Financing Bank and accrues interest at fixed rates between 2.395% and 3.633%, which matures in 2037.
Pinnacle Repowering Partnership HoldCo LLC
On March 10, 2021, the Company entered into a financing agreement for non-recourse debt for a total commitment of $126 million related to the repowering of the Pinnacle wind project. The debt consists of a construction loan at an interest rate of LIBOR plus 1.00%. The Company'sCompany’s initial borrowings of $79 million were utilized to repay $53 million of the outstanding balance under the Tapestry Wind LLC financing agreement, which related to the Pinnacle wind project, to pay vendor invoices and fees and to acquire certain equipment from Clearway Renew LLC to be utilized in the repowering project. On December 15, 2021, the Company repaid the outstanding principal amount of $117 million.
Rosamond Central (Rosie Class B LLC)
On December 21, 2020, as part of the acquisition of Rosie TargetCo LLC, as further descried in Note 3, Acquisitions and Dispositions, the Company assumed the Amended and Restated Financing Agreement, which provided for a construction loan of up to $91 million, a cash equity bridge loan of up to $24 million and an investment tax credit loan of up to $132 million.
On December 31, 2020, Rosie Class B, LLC converted the construction loan to a $80 million term loan and repaid the investment tax credit loan of $130 million, utilizing tax equity funding. The term loan bears annual interest at a rate of LIBOR plus an applicable margin, which is 1.75% per annum through the third anniversary of the term conversion, and 2.00% per annum thereafter through the maturity date of December 31, 2027. In addition, Rosie Class B LLC is party to several letter of credit facility agreements, not to exceed $23 million. As of December 31, 2021, a total of $17 million in letters of credit were outstanding.
Consolidation of DGPV Holdco 3
Upon consolidation of DGPV Holdco 3, as described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, the Company consolidates additional non-recourse debt for certain subsidiaries as further described below.
Renew CS4 Borrower LLC, or CS4 Borrower, a consolidated subsidiary of DGPV Holdco 3, is party to a credit agreement for construction loans up to $97 million, an investment tax credit bridge loan, or ITC bridge loan, for up to $90 million and letter of credit facilities up to $5 million. The construction loan and the ITC bridge loan both have an interest rate of LIBOR plus an applicable margin of 2.00% per annum. As of June 30, 2020, all construction loans were converted to term loans and the ITC bridge loans were repaid in connection with tax equity funding. The term loan was repaid on November 2, 2020 with the proceeds of the term loan issued by DG-CS Master Borrower LLC, as described below.
Chestnut Borrower LLC, a consolidated subsidiary of DGPV Holdco 3, is party to a credit agreement for term loans of up to $120 million and letters of credit of up to $8 million. The loans were repaid on November 2, 2020 with the proceeds of the term loan issued by DG-CS Master Borrower LLC, as described below
DG-CS Master Borrower LLC
On November 2, 2020, DG-CS Master Borrower LLC, a wholly-owned subsidiary of Clearway Energy Operating LLC, entered into a financing arrangement, which included the issuance of a $467 million term loan, as well as $30 million in letters of credit in support of debt service. The term loan bears interest at 3.51% and matures on September 30, 2040. The proceeds from the loan were utilized to repay existing project-level debt outstanding for Chestnut Borrower LLC, Renew Solar CS 4 Borrower LLC, DGPV 4 Borrower LLC and Puma Class B LLC of $107 million, $102 million, $92 million and $73 million, respectively and unwind related interest rate swaps in the amount of $42 million. The remaining proceeds were utilized to pay related fees and expenses and in part to acquire the Class B membership interests in the DGPV Holdco Entities and an SREC contract from CEG as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. Concurrent with the refinancing, the projects were transferred under DG-CS Master Borrower LLC and the obligations under the financing arrangement are supported by the Company's interest in the projects.
Utah Solar Holdings, LLC
On September 1, 2020, Utah Solar Holdings, LLC, or Utah Solar, entered into a financing arrangement, which included the issuance of approximately $296 million in senior secured notes supported by the Company’s interest in the Utah projects (Four Brothers, Granite Mountain and Iron Springs, previously defined as the Utah Solar Portfolio), as well as $16 million in letters of credit in support of debt service obligations. The notes bear interest at 3.59% per annum and mature on December 31, 2036. The proceeds from the issuance were utilized to repay existing debt outstanding of approximately $247 million for the Utah projects and to unwind the related interest rate swaps in the amount of $33 million. The remaining proceeds were utilized to pay related fees and expenses, with the remaining $9 million distributed to Clearway Energy Operating LLC.
NIMH Solar LLC
On September 30, 2020, the Alpine, Blythe and Roadrunner projects were transferred under NIMH Solar LLC, a wholly- owned subsidiary of Clearway Energy Operating LLC. Concurrently, total project-level debt outstanding for Alpine, Blythe and Roadrunner of $158 million was assigned to NIMH Solar LLC. The consolidated facility was amended to a term loan for$193 million, as well as $16 million in letters of credit in support of debt service and project obligations. The term loan bears interest at an annual rate of LIBOR, plus an applicable margin, which is 2.00% per annum through the third anniversary of closing, and 2.125% per annum thereafter through the maturity date in September 2024. As a result of the amendment the Company received $35 million, which was utilized to pay related fees and expenses and along with existing project level cash, provided a distribution to Clearway Energy Operating LLC of $45 million. The obligations under the financing arrangement are supported by the Company’s interests in the projects.
Interest Rate Swaps — Project Financings
Many of the Company'sCompany’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 valueamount and will receive quarterly the equivalent of a floating interest payment based on the same notional value.amount. All interest rate swap payments by the project subsidiary and its counterparty are made quarterly and the LIBOR or 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'sCompany’s project level debt as of December 31, 2021:2022:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | % of Principal | | Fixed Interest Rate | | Floating Interest Rate | | Notional Amount at December 31, 2021 (In millions) | | Effective Date | | Maturity Date |
| Avra Valley | | 88 | % | | 2.33 | % | | 3-Month LIBOR | | $ | 35 | | | November 30, 2012 | | November 30, 2030 |
| Alta Wind Asset Management | | 100 | % | | 2.47 | % | | 3-Month LIBOR | | 13 | | | May 22, 2013 | | May 15, 2031 |
| Borrego | | 100 | % | | 0.476 | % | | 3-Month LIBOR | | 10 | | | June 30, 2020 | | December 31, 2024 |
| Buckthorn Solar | | 81 | % | | Various | | 3-Month LIBOR | | 100 | | | February 28, 2018 | | December 31, 2041 |
| Carlsbad | | 100 | % | | Various | | 3-Month LIBOR | | 136 | | | Various | | September 30, 2027 |
| El Segundo | | 100 | % | | Various | | 3-Month LIBOR | | 193 | | | Various | | Various |
| Kansas South | | 75 | % | | 2.368 | % | | 6-Month LIBOR | | 15 | | | June 28, 2013 | | December 31, 2030 |
| Kawailoa Solar | | 94 | % | | Various | | 3-Month LIBOR | | 74 | | | November 30, 2019 | | October 31, 2040 |
| Laredo Ridge | | 100 | % | | Various | | 3-Month LIBOR | | 72 | | | December 17, 2014 | | December 31, 2028 |
| Marsh Landing | | 100 | % | | Various | | 3-Month LIBOR | | 84 | | | June 28, 2013 | | June 30, 2023 |
| NIMH Solar LLC | | 100 | % | | Various | | 3-Month LIBOR | | 176 | | | September 30, 2020 | | Various |
| Oahu Solar | | 96 | % | | Various | | 3-Month LIBOR | | 83 | | | November 30, 2019 | | October 31, 2040 |
| Rosie Class B | | 95 | % | | 1.446 | % | | 3-Month LIBOR | | 74 | | | December 31, 2020 | | Various |
| South Trent | | 90 | % | | 3.847 | % | | 3-Month LIBOR | | 31 | | | June 14, 2019 | | June 30, 2028 |
| Tapestry | | 100 | % | | Various | | 3-Month LIBOR | | 85 | | | Various | | Various |
| Viento Funding II | | 100 | % | | 3.03 | % | | 6-Month LIBOR | | 29 | | | Various | | Various |
| Viento Funding II | | 100 | % | | 4.985 | % | | 6-Month LIBOR | | 21 | | | July 11, 2023 | | June 30, 2028 |
| Walnut Creek Energy | | 90 | % | | 3.543 | % | | 3-Month LIBOR | | 66 | | | June 28, 2013 | | May 31, 2023 |
| WCEP Holdings | | 97 | % | | 4.003 | % | | 3-Month LIBOR | | 29 | | | June 28, 2013 | | May 31, 2023 |
| Total | | | | | | | | $ | 1,326 | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | % of Principal | | Fixed Interest Rate | | Floating Interest Rate | | Notional Amount at December 31, 2022 (In millions) | | Effective Date | | Maturity Date |
| Avra Valley | | 88 | % | | 2.333 | % | | 3-Month LIBOR | | $ | 32 | | | November 30, 2012 | | November 30, 2030 |
| Alta Wind Asset Management | | 100 | % | | 2.470 | % | | 3-Month LIBOR | | 12 | | | May 22, 2013 | | May 15, 2031 |
| Borrego | | 100 | % | | 0.476 | % | | 3-Month LIBOR | | 6 | | | June 30, 2020 | | December 31, 2024 |
| Buckthorn Solar | | 81 | % | | Various | | 3-Month LIBOR | | 96 | | | February 28, 2018 | | December 31, 2041 |
| Carlsbad Energy Holdings | | 100 | % | | Various | | 3-Month LIBOR | | 115 | | | Various | | September 30, 2027 |
| Capistrano Wind Portfolio | | 95 | % | | Various | | 3-Month LIBOR | | 148 | | | Various | | Various |
| Kansas South | | 75 | % | | 2.368 | % | | 6-Month LIBOR | | 14 | | | June 28, 2013 | | December 31, 2030 |
| Marsh Landing | | 100 | % | | Various | | 3-Month LIBOR | | 19 | | | June 28, 2013 | | June 30, 2023 |
| Mililani I | | 94 | % | | 2.041 | % | | 3-Month LIBOR | | 44 | | | September 30, 2022 | | September 30, 2042 |
| NIMH Solar | | 100 | % | | Various | | 3-Month LIBOR | | 163 | | | September 30, 2020 | | Various |
| Oahu Solar | | 96 | % | | Various | | 3-Month LIBOR | | 80 | | | November 30, 2019 | | October 31, 2040 |
| Rosie Class B | | 95 | % | | 1.446 | % | | 3-Month LIBOR | | 73 | | | December 31, 2020 | | Various |
| South Trent | | 90 | % | | 3.847 | % | | 3-Month LIBOR | | 27 | | | June 14, 2019 | | June 30, 2028 |
| Viento Funding II | | 90 | % | | 2.530 | % | | 3-Month SOFR | | 165 | | | Various | | Various |
| Waiawa | | 50 | % | | 2.088 | % | | 3-Month LIBOR | | 48 | | | December 31, 2022 | | December 31, 2042 |
| Walnut Creek | | 94 | % | | 3.543 | % | | 3-Month LIBOR | | 18 | | | June 28, 2013 | | May 31, 2023 |
| WCEP Holdings | | 92 | % | | 4.003 | % | | 3-Month LIBOR | | 24 | | | June 28, 2013 | | May 31, 2023 |
| Total | | | | | | | | $ | 1,084 | | | | | |
Annual Maturities
Annual payments based on the maturities of the Company'sCompany’s debt, for the years ending after December 31, 2021,2022, are as follows:
| | | | | |
| (In millions) |
| 2022 | $ | 772 | |
| 2023 | 709 | |
| 2024 | 392 | |
2025 (a) | 369 | |
2026 (a) | 422 | |
Thereafter (a) | 5,537 | |
| Total | $ | 8,201 | |
| |
| |
| | | | | |
| (In millions) |
2023 (a) | $ | 421 | |
| 2024 | 410 | |
| 2025 | 382 | |
2026 | 361 | |
2027 | 399 | |
| Thereafter | 4,899 | |
| Total | $ | 6,872 | |
| |
| |
(a) Annual payments basedAt December 31, 2022, amount includes $97 million recorded in long-term debt on the maturities of Thermal Business long-term debt reclassified to held for sale in the fourth quarter of 2021 are $4 million, $15 million and $404 millionCompany’s consolidated balance sheet that is due in 2025, 20262023 and thereafter, respectively.is either being funded through long-term equity contributions or is converting to long-term debt.
Note 11 — Members'Members’ Equity
The following table lists the distributions paid on the Company'sCompany’s Class A, Class B, Class C and Class D units during the year ended December 31, 2021:2022:
| | | Fourth Quarter 2021 | | Third Quarter 2021 | | Second Quarter 2021 | | First Quarter 2021 | | Fourth Quarter 2022 | | Third Quarter 2022 | | Second Quarter 2022 | | First Quarter 2022 |
| Distributions per Class A and Class B units | Distributions per Class A and Class B units | $ | 0.3400 | | | $ | 0.3345 | | | $ | 0.3290 | | | $ | 0.3240 | | Distributions per Class A and Class B units | $ | 0.3672 | | | $ | 0.3604 | | | $ | 0.3536 | | | $ | 0.3468 | |
| Distributions per Class C and Class D units | Distributions per Class C and Class D units | 0.3400 | | | 0.3345 | | | 0.3290 | | | 0.3240 | | Distributions per Class C and Class D units | 0.3672 | | | 0.3604 | | | 0.3536 | | | 0.3468 | |
On February 17, 2022,15, 2023, the Company declared a quarterly distribution on its Class A, Class B, Class C and Class D units of $0.3468$0.3745 per unit payable on March 15, 2022.2023.
In addition to the quarterly distributions, the Company paid $19 million in additional distributions, $11 million of which was distributed to Clearway, Inc. and $8 million of which was distributed to CEG, during the third quarter of 2022 in order for Clearway, Inc. to make certain tax payments associated with the sale of the Thermal Business.
Note 12 — Segment Reporting
The Company’s segment structure reflects how management currently operates and allocates resources. The Company'sCompany’s businesses are segregated based on conventional power generation, renewable businesses, which consist of solar and wind, and the Thermal Business, which is held for salewas sold on May 1, 2022, as of December 31, 2021.further described in Note 3, Acquisitions and Dispositions. The Corporate segment reflects the Company'sCompany’s corporate costs and includes eliminating entries. The Company'sCompany’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).
The Company generated more than 10% of its revenues from the following customers for the years ended December 31, 2022, 2021 2020 and 2019:2020:
| | | 2021 | | 2020 | | 2019 | | 2022 | | 2021 | | 2020 |
| Customer | Customer | Conventional | | Renewables | | Conventional | | Renewables | | Conventional | | Renewables | Customer | Conventional | | Renewables | | Conventional | | Renewables | | Conventional | | Renewables |
| SCE | SCE | 17% | | 16% | | 18% | | 16% | | 21% | | 19% | SCE | 17% | | 17% | | 17% | | 16% | | 18% | | 16% |
| PG&E | PG&E | 10% | | 13% | | 10% | | 8% | | 12% | | 10% | PG&E | 10% | | 15% | | 10% | | 13% | | 10% | | 8% |
| | | Year ended December 31, 2021 | | Year ended December 31, 2022 |
| (In millions) | (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate (a) | | Total | (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate (a) | | Total |
| Operating revenues | Operating revenues | $ | 441 | | | $ | 641 | | | $ | 204 | | | $ | — | | | $ | 1,286 | | Operating revenues | $ | 417 | | | $ | 696 | | | $ | 77 | | | $ | — | | | $ | 1,190 | |
| Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 90 | | | 229 | | | 134 | | | (2) | | | 451 | | Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 89 | | | 298 | | | 50 | | | (2) | | | 435 | |
| Depreciation, amortization and accretion | Depreciation, amortization and accretion | 132 | | | 354 | | | 23 | | | — | | | 509 | | Depreciation, amortization and accretion | 131 | | | 381 | | | — | | | — | | | 512 | |
| Impairment losses | Impairment losses | — | | | 6 | | | — | | | — | | | 6 | | Impairment losses | — | | | 16 | | | — | | | — | | | 16 | |
| General and administrative | General and administrative | — | | | — | | | 4 | | | 34 | | | 38 | | General and administrative | — | | | — | | | 2 | | | 36 | | | 38 | |
| Transaction and integration costs | Transaction and integration costs | — | | | — | | | — | | | 7 | | | 7 | | Transaction and integration costs | — | | | — | | | — | | | 7 | | | 7 | |
| Development costs | Development costs | — | | | — | | | 4 | | | 2 | | | 6 | | Development costs | — | | | — | | | 2 | | | — | | | 2 | |
| Operating income (loss) | 219 | | | 52 | | | 39 | | | (41) | | | 269 | | |
| Total operating costs and expenses | | Total operating costs and expenses | 220 | | | 695 | | | 54 | | | 41 | | | 1,010 | |
| Gain on sale of business | | Gain on sale of business | — | | | — | | | — | | | 1,292 | | | 1,292 | |
| Operating income | | Operating income | 197 | | | 1 | | | 23 | | | 1,251 | | | 1,472 | |
| Equity in earnings of unconsolidated affiliates | Equity in earnings of unconsolidated affiliates | 6 | | | 26 | | | — | | | — | | | 32 | | Equity in earnings of unconsolidated affiliates | 3 | | | 26 | | | — | | | — | | | 29 | |
| | Other income, net | Other income, net | — | | | 2 | | | 1 | | | — | | | 3 | | Other income, net | 1 | | | 6 | | | — | | | 10 | | | 17 | |
| Loss on debt extinguishment | Loss on debt extinguishment | — | | | (1) | | | — | | | (52) | | | (53) | | Loss on debt extinguishment | — | | | (2) | | | — | | | — | | | (2) | |
| Interest expense, net | (53) | | | (142) | | | (18) | | | (99) | | | (312) | | |
| Interest expense | | Interest expense | (40) | | | (87) | | | (6) | | | (99) | | | (232) | |
| Income (loss) before income taxes | Income (loss) before income taxes | 172 | | | (63) | | | 22 | | | (192) | | | (61) | | Income (loss) before income taxes | 161 | | | (56) | | | 17 | | | 1,162 | | | 1,284 | |
| Income tax expense | Income tax expense | — | | | 2 | | | — | | | — | | | 2 | | Income tax expense | — | | | 2 | | | — | | | — | | | 2 | |
| Net Income (Loss) | Net Income (Loss) | 172 | | | (65) | | | 22 | | | (192) | | | (63) | | Net Income (Loss) | 161 | | | (58) | | | 17 | | | 1,162 | | | 1,282 | |
| | Net Income (Loss) Attributable to Clearway Energy LLC | $ | 172 | | | $ | 109 | | | $ | 22 | | | $ | (193) | | | $ | 110 | | |
| Net Income Attributable to Clearway Energy LLC | | Net Income Attributable to Clearway Energy LLC | $ | 161 | | | $ | 49 | | | $ | 17 | | | $ | 1,161 | | | $ | 1,388 | |
| Balance Sheet | Balance Sheet | | | | | | | | | | Balance Sheet | | | | | | | | | |
| Equity investment in affiliates | $ | 86 | | | $ | 295 | | | $ | — | | | $ | — | | | $ | 381 | | |
Capital expenditures (b) | 12 | | | 77 | | | 29 | | | 1 | | | 119 | | |
Total Assets (c) | $ | 2,442 | | | $ | 9,603 | | | $ | 631 | | | $ | 42 | | | $ | 12,718 | | |
| Equity investments in affiliates | | Equity investments in affiliates | $ | 82 | | | $ | 282 | | | $ | — | | | $ | — | | | $ | 364 | |
Capital expenditures (b)(c) | | Capital expenditures (b)(c) | 11 | | | 33 | | | 11 | | | 1 | | | 56 | |
| Total Assets | | 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 assets were reclassified to held for sale during the fourth quarter of 2021.on May 1, 2022.
| | | Year ended December 31, 2020 | | Year ended December 31, 2021 |
| (In millions) | (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate (a) | | Total | (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate (a) | | Total |
| Operating revenues | Operating revenues | $ | 437 | | | $ | 569 | | | $ | 193 | | | $ | — | | | $ | 1,199 | | Operating revenues | $ | 441 | | | $ | 641 | | | $ | 204 | | | $ | — | | | $ | 1,286 | |
| Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 90 | | | 147 | | | 131 | | | (2) | | | 366 | | Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 90 | | | 229 | | | 134 | | | (2) | | | 451 | |
| Depreciation amortization and accretion | 132 | | | 264 | | | 32 | | | — | | | 428 | | |
| Depreciation, amortization and accretion | | Depreciation, amortization and accretion | 132 | | | 354 | | | 23 | | | — | | | 509 | |
| Impairment losses | Impairment losses | — | | | 24 | | | — | | | — | | | 24 | | Impairment losses | — | | | 6 | | | — | | | — | | | 6 | |
| General and administrative | General and administrative | — | | | — | | | 3 | | | 30 | | | 33 | | General and administrative | — | | | — | | | 4 | | | 34 | | | 38 | |
| Transaction and integration costs | Transaction and integration costs | — | | | — | | | — | | | 9 | | | 9 | | Transaction and integration costs | — | | | — | | | — | | | 7 | | | 7 | |
| Development costs | Development costs | — | | | — | | | 5 | | | — | | | 5 | | Development costs | — | | | — | | | 4 | | | 2 | | | 6 | |
| Operating income (loss) | Operating income (loss) | 215 | | | 134 | | | 22 | | | (37) | | | 334 | | Operating income (loss) | 219 | | | 52 | | | 39 | | | (41) | | | 269 | |
| Equity in earnings (losses) of unconsolidated affiliates | 8 | | | (1) | | | — | | | — | | | 7 | | |
| Impairment loss on investment | — | | | (8) | | | — | | | — | | | (8) | | |
| Gain on sale of unconsolidated affiliates | — | | | — | | | — | | | 49 | | | 49 | | |
| Equity in earnings of unconsolidated affiliates | | Equity in earnings of unconsolidated affiliates | 6 | | | 26 | | | — | | | — | | | 32 | |
| | Other income, net | Other income, net | 1 | | | 4 | | | — | | | (1) | | | 4 | | Other income, net | — | | | 2 | | | 1 | | | — | | | 3 | |
| Loss on debt extinguishment | Loss on debt extinguishment | — | | | (21) | | | — | | | (3) | | | (24) | | Loss on debt extinguishment | — | | | (1) | | | — | | | (52) | | | (53) | |
| Interest expense, net | (84) | | | (216) | | | (19) | | | (95) | | | (414) | | |
| Interest expense | | Interest expense | (53) | | | (142) | | | (18) | | | (99) | | | (312) | |
| Income (loss) before income taxes | | Income (loss) before income taxes | 172 | | | (63) | | | 22 | | | (192) | | | (61) | |
| Income tax expense | | Income tax expense | — | | | 2 | | | — | | | — | | | 2 | |
| Net Income (Loss) | Net Income (Loss) | 140 | | | (108) | | | 3 | | | (87) | | | (52) | | Net Income (Loss) | 172 | | | (65) | | | 22 | | | (192) | | | (63) | |
| | Net Income (Loss) Attributable to Clearway Energy LLC | Net Income (Loss) Attributable to Clearway Energy LLC | $ | 140 | | | $ | 4 | | | $ | 3 | | | $ | (86) | | | $ | 61 | | Net Income (Loss) Attributable to Clearway Energy LLC | $ | 172 | | | $ | 109 | | | $ | 22 | | | $ | (193) | | | $ | 110 | |
| Balance Sheet | Balance Sheet | | | | | | | | | | Balance Sheet | | | | | | | | | |
| Equity investments in affiliates | Equity investments in affiliates | $ | 90 | | | $ | 651 | | | $ | — | | | $ | — | | | $ | 741 | | Equity investments in affiliates | $ | 86 | | | $ | 295 | | | $ | — | | | $ | — | | | $ | 381 | |
Capital expenditures (b) | Capital expenditures (b) | 12 | | | 44 | | | 50 | | | — | | | 106 | | Capital expenditures (b) | 12 | | | 77 | | | 29 | | | 1 | | | 119 | |
| Total Assets | Total Assets | $ | 2,575 | | | $ | 7,157 | | | $ | 627 | | | $ | 129 | | | $ | 10,488 | | Total Assets | $ | 2,442 | | | $ | 9,603 | | | $ | 631 | | | $ | 42 | | | $ | 12,718 | |
(a) Includes eliminations
(b) Includes accruals
| | | Year ended December 31, 2019 | | Year ended December 31, 2020 |
| (In millions) | (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate (a) | | Total | (In millions) | Conventional Generation | | Renewables | | Thermal | | Corporate (a) | | Total |
| Operating revenues | Operating revenues | $ | 346 | | | $ | 485 | | | $ | 201 | | | $ | — | | | $ | 1,032 | | Operating revenues | $ | 437 | | | $ | 569 | | | $ | 193 | | | $ | — | | | $ | 1,199 | |
| Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 60 | | | 143 | | | 134 | | | — | | | 337 | | Cost of operations, exclusive of depreciation, amortization and accretion shown separately below | 90 | | | 147 | | | 131 | | | (2) | | | 366 | |
| Depreciation amortization and accretion | 103 | | | 271 | | | 27 | | | — | | | 401 | | |
| Depreciation, amortization and accretion | | Depreciation, amortization and accretion | 132 | | | 264 | | | 32 | | | — | | | 428 | |
| Impairment losses | Impairment losses | — | | | 14 | | | 19 | | | — | | | 33 | | Impairment losses | — | | | 24 | | | — | | | — | | | 24 | |
| General and administrative | General and administrative | — | | | 1 | | | 3 | | | 23 | | | 27 | | General and administrative | — | | | — | | | 3 | | | 30 | | | 33 | |
| Transaction and integration costs | Transaction and integration costs | — | | | — | | | — | | | 3 | | | 3 | | Transaction and integration costs | — | | | — | | | — | | | 9 | | | 9 | |
| Development costs | Development costs | — | | | — | | | 5 | | | — | | | 5 | | Development costs | — | | | — | | | 5 | | | — | | | 5 | |
| Operating income (loss) | Operating income (loss) | 183 | | | 56 | | | 13 | | | (26) | | | 226 | | Operating income (loss) | 215 | | | 134 | | | 22 | | | (37) | | | 334 | |
| Equity in earnings of unconsolidated affiliates | 9 | | | 74 | | | — | | | — | | | 83 | | |
| Equity in earnings (losses) of unconsolidated affiliates | | Equity in earnings (losses) of unconsolidated affiliates | 8 | | | (1) | | | — | | | — | | | 7 | |
| Impairment loss on investment | | Impairment loss on investment | — | | | (8) | | | — | | | — | | | (8) | |
| Gain on sale of unconsolidated affiliates | | Gain on sale of unconsolidated affiliates | — | | | — | | | — | | | 49 | | | 49 | |
| Other income, net | Other income, net | 2 | | | 6 | | | — | | | 1 | | | 9 | | Other income, net | 1 | | | 4 | | | — | | | (1) | | | 4 | |
| Loss on debt extinguishment | Loss on debt extinguishment | — | | | (1) | | | — | | | (15) | | | (16) | | Loss on debt extinguishment | — | | | (21) | | | — | | | (3) | | | (24) | |
| Interest expense, net | (59) | | | (239) | | | (18) | | | (87) | | | (403) | | |
| Interest expense | | Interest expense | (84) | | | (216) | | | (19) | | | (95) | | | (414) | |
| Net Income (Loss) | Net Income (Loss) | 135 | | | (104) | | | (5) | | | (127) | | | (101) | | Net Income (Loss) | 140 | | | (108) | | | 3 | | | (87) | | | (52) | |
| | Net Income (Loss) Attributable to Clearway Energy LLC | Net Income (Loss) Attributable to Clearway Energy LLC | $ | 135 | | | $ | (33) | | | $ | (5) | | | $ | (127) | | | $ | (30) | | Net Income (Loss) Attributable to Clearway Energy LLC | $ | 140 | | | $ | 4 | | | $ | 3 | | | $ | (86) | | | $ | 61 | |
(a) Includes eliminations
Note 13 — 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'sCompany’s consolidated balance sheet.sheets. The disclosures below summarize the Company'sCompany’s material related party transactions with CEG and its subsidiaries that are included in the Company'sCompany’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 $71 million, $56 million $37 million and $31$37 million for the years ended December 31, 2022, 2021 2020 and 2019,2020, respectively. There was a balance of $9$14 million and $10$9 million due to RENOM as of December 31, 20212022 and 2020,2021, 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'sCompany’s subsidiaries. The Company incurred expenses under these agreements of $16 million, $14 million $10 million and $7$10 million for the years ended December 31, 2022, 2021 2020 and 2019,2020, respectively. There was a balance of $3 million and $2 million due to CEG as of both December 31, 2022 and 2021, and 2020.respectively.
CEG Master Services Agreements
The Company is a party to Master Services Agreements with CEG, or MSAs, 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, 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, $4 million $2 million and $1$2 million under these agreements for the years ended December 31, 2022, 2021 2020 and 2019,2020, respectively.
Note 14 — Commitments and Contingencies
Gas and Transportation Commitments
The Company has entered into contractual arrangements to procure power, fuel and associated transportation services for the Thermal Business. For the years ended December 31, 2022, 2021 2020 and 2019,2020, the Company purchased $20 million, $40 million, $32 million, and $38$32 million, respectively, under such arrangements.
AsOn May 1, 2022, the Company completed the sale of December 31, 2021,100% of its interests in the Company's future minimum commitments under such outstanding agreements are estimated as follows:
| | | | | |
| (In millions) |
| 2022 | $ | 7 | |
| 2023 | 1 | |
| 2024 | — | |
| 2025 | — | |
| 2026 | — | |
| Thereafter | — | |
| Total | $ | 8 | |
Thermal Business to KKR. For further details of the Thermal Disposition, refer to Note 3, Acquisitions and Dispositions.
Contingencies
The Company'sCompany’s material legal proceedings areproceeding is described below. The Company believes that it has a valid defensesdefense to thesethis legal proceedingsproceeding and intends to defend themit vigorously. 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 has established an adequate reserve for the mattersmatter discussed below. 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 the legal proceedingsproceeding below or reasonably estimate the scope or amount of any associated costs and potential liabilities. As additional information becomes available, management adjusts its assessment and estimatesestimate of such contingenciesthe contingency accordingly. Because litigation is subject to inherent uncertainties and unfavorable rulings or developments, it is possible that the ultimate resolution of the Company'sCompany’s liabilities and contingencies could be at amounts that are different from its currently recorded reserves and that such difference could be material.
In addition to the legal proceedingsproceeding noted below, the Company and its subsidiaries are party to other litigation or legal proceedings arising in the ordinary course of business. In management'smanagement’s opinion, the disposition of these ordinary course matters will not materially adversely affect the Company'sCompany’s consolidated financial position, results of operations, or cash flows.
Nebraska Public Power District Litigation
On January 11, 2019, Nebraska Public Power District, or NPPD, sent written notice to certain of the Company's subsidiaries which own the Laredo Ridge and Elkhorn Ridge wind projects alleging an event of default under each of the PPAs between NPPD and the projects. NPPD alleges that the Company moved forward with certain transactions without obtaining the consent of NPPD. NPPD threatened to terminate the applicable PPAs by February 11, 2019 if the alleged default was not cured. The Company filed a motion for a temporary restraining order and preliminary injunction in the U.S. District Court for the District of Nebraska relating to the Laredo Ridge project, and a similar motion in the District Court of Knox County, Nebraska for the Elkhorn Ridge project, to enjoin NPPD from taking any actions related to the PPAs. On February 19, 2019, the U.S. District Court in the Laredo Ridge matter approved a stipulation between the parties to provide for an injunction preventing NPPD from terminating the PPA pending disposition of the litigation. On February 26, 2019, the Knox County District Court approved a similar stipulation relating to the Elkhorn Ridge project. On April 13, 2020, the U.S. District Court granted the wind projects' motion for summary judgment and permanently enjoined NPPD from terminating the PPAs in reliance on the alleged events of default. The U.S. District Court decision was appealed by NPPD on May 11, 2020. On August 24, 2021, the U.S. Court of Appeals for the Eighth Circuit affirmed the U.S. District Court decision granting summary judgment. On October 18, 2021, the Appeals Court denied a petition by NPPD for rehearing and a request that the case be heard by the full Appeals Court. On November 2, 2021, the Knox County District Court issued an order dismissing the case with respect to the Elkhorn Ridge project. Accordingly, the federal case and the state case are now concluded.
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. The case is currently in discovery and is expected to proceed to trial in June 2023. Buckthorn Westex believes the allegations of Georgetown are meritless, and Buckthorn Westex is vigorously defending its rights under the PPA.
Note 15 — 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 aswhen the expense is incurred.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.
Lease expense for the years ended December 31, 2022, 2021 2020 and 20192020 was comprised of the following:
| | (In millions) | (In millions) | | December 31, 2021 | | December 31, 2020 | | December 31, 2019 | (In millions) | | December 31, 2022 | | December 31, 2021 | | December 31, 2020 |
| Operating lease cost - Fixed | Operating lease cost - Fixed | | $ | 27 | | | $ | 19 | | | $ | 13 | | Operating lease cost - Fixed | | $ | 36 | | | $ | 27 | | | $ | 19 | |
| | Operating lease cost - Variable | Operating lease cost - Variable | | 15 | | | 9 | | | 8 | | Operating lease cost - Variable | | 11 | | | 15 | | | 9 | |
| Total lease cost | Total lease cost | | $ | 42 | | | $ | 28 | | | $ | 21 | | Total lease cost | | $ | 47 | | | $ | 42 | | | $ | 28 | |
Operating lease information as of December 31, 20212022 and 20202021 was as follows:
| | (In millions, except term and rate) | (In millions, except term and rate) | | December 31, 2021 | | December 31, 2020 | (In millions, except term and rate) | | December 31, 2022 | | December 31, 2021 |
Right-of-use assets - operating leases, net (a) (b) | | $ | 550 | | $ | 337 | | |
Right-of-use assets - operating leases, net | | Right-of-use assets - operating leases, net | | $ | 527 | | | $ | 550 | |
| Short-term lease liability - operating leases (c)(a) | Short-term lease liability - operating leases (c)(a) | | $ | 8 | | $ | 8 | | Short-term lease liability - operating leases (c)(a) | | $ | 6 | | | $ | 8 | |
| Long-term lease liability - operating leases | Long-term lease liability - operating leases | | 561 | | 345 | | Long-term lease liability - operating leases | | 548 | | | 561 | |
Total lease liabilities (a) (b) | | $ | 569 | | $ | 353 | | |
| Total lease liabilities | | Total lease liabilities | | $ | 554 | | | $ | 569 | |
| | Weighted average remaining lease term (in years) | Weighted average remaining lease term (in years) | | 28 | | 25 | Weighted average remaining lease term (in years) | | 27 | | 28 |
| Weighted average discount rate | Weighted average discount rate | | 3.5 | % | | 4.3 | % | Weighted average discount rate | | 4.1 | % | | 3.5 | % |
| | Cash paid for operating leases | Cash paid for operating leases | | $ | 26 | | | $ | 19 | | Cash paid for operating leases | | $ | 28 | | | $ | 26 | |
(a) Increases in right-of-use assets and total lease liabilities are primarily due to third-party and drop down asset acquisitions, as further described in Note 3, Acquisitions and Dispositions.
(b)Thermal Business right-of-use assets and lease liabilities were reclassified to held for sale during the fourth quarter of 2021.
(c)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, 20212022 and 2020.2021.
Minimum future rental payments of operating lease liabilities as of December 31, 20212022 are as follows:
| | | (In millions) | | (In millions) |
| 2022 | | $ | 28 | | |
| 2023 | 2023 | | 28 | | 2023 | | $ | 28 | |
| 2024 | 2024 | | 28 | | 2024 | | 30 | |
| 2025 | 2025 | | 28 | | 2025 | | 30 | |
| 2026 | 2026 | | 29 | | 2026 | | 31 | |
| 2027 | | 2027 | | 32 | |
| Thereafter | Thereafter | | 801 | | Thereafter | | 831 | |
Total lease payments (a) | Total lease payments (a) | | 942 | | Total lease payments (a) | | 982 | |
| Less imputed interest | Less imputed interest | | (352) | | Less imputed interest | | (428) | |
| Total lease liability - operating leases | Total lease liability - operating leases | | $ | 590 | | Total lease liability - operating leases | | $ | 554 | |
(a) Minimum future rental paymentsMililani I Lease Agreement
The Mililani I project is party to a land lease agreement with a wholly-owned subsidiary of CEG. The project is leasing the Thermal Business operatingland for a period of 36 years. The Company has a lease liabilities classifiedliability of $20 million as held for sale are $1of December 31, 2022 and a corresponding right-of-use asset of $19 million for eachrelated to the lease as of 2022, 2023, 2024, 2025 and 2026, with $31 million due thereafter.December 31, 2022.
Oahu Solar Lease Agreements
The Oahu Solar projects are party to various land lease agreements with a wholly-owned subsidiary of CEG. The projects are leasing the land for a period of 35 years, with the ability to renew the lease for 2two additional five-year periods. The Company has a lease liability of $20 million as of both December 31, 2022 and 2021 and 2020 anda corresponding right-of-use asset of $18 million related to the lease of $17 million and $18 million as of both December 31, 2022 and 2021, and 2020.respectively.
Rosamond Central Lease Agreement
The Rosamond Central project is party to a land lease agreement with a wholly-owned subsidiary of CEG. The project is leasing the land for a period of 35 years, with the ability to renew the lease for 2two additional five-year periods. The Company has a lease liability of $12 million as of both December 31, 2022 and 2021 and 2020 anda corresponding right-of-use asset of $11 million related to the lease as of both December 31, 20212022 and 2020.2021.
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 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. The remaining lease met the criteria of a sales-type lease and the impact of this sales-type lease to the consolidated financial statements was immaterial. Certain of these 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 and capacity revenue are related to the Company’s operating leases:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Conventional Generation | | Renewables | | Thermal | | Total |
| December 31, 2021 | | (In millions) |
| Energy revenue | | $ | 9 | | | $ | 716 | | | $ | 2 | | | $ | 727 | |
| Capacity revenue | | 455 | | | — | | | — | | | 455 | |
| Operating revenue | | $ | 464 | | | $ | 716 | | | $ | 2 | | | $ | 1,182 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Conventional Generation | | Renewables | | Thermal | | Total |
| December 31, 2020 | | (In millions) |
| Energy revenue | | $ | 10 | | | $ | 554 | | | $ | 2 | | | $ | 566 | |
| Capacity revenue | | 451 | | | — | | | — | | | 451 | |
| Operating revenue | | $ | 461 | | | $ | 554 | | | $ | 2 | | | $ | 1,017 | |
| | | Conventional Generation | | Renewables | | Thermal | | Total | | Conventional Generation | | Renewables | | Thermal | | Total |
| December 31, 2019 | | (In millions) | |
| December 31, 2022 | | December 31, 2022 | | (In millions) |
| Energy revenue | Energy revenue | | $ | 5 | | | $ | 509 | | | $ | 2 | | | $ | 516 | | Energy revenue | | $ | 6 | | | $ | 809 | | | $ | 1 | | | $ | 816 | |
| Capacity revenue | Capacity revenue | | 348 | | | — | | | — | | | 348 | | Capacity revenue | | 435 | | | — | | | — | | | 435 | |
| Operating revenue | Operating revenue | | $ | 353 | | | $ | 509 | | | $ | 2 | | | $ | 864 | | Operating revenue | | $ | 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 revenue | | $ | 464 | | | $ | 716 | | | $ | 2 | | | $ | 1,182 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Conventional Generation | | Renewables | | Thermal | | Total |
| December 31, 2020 | | (In millions) |
| Energy revenue | | $ | 10 | | | $ | 554 | | | $ | 2 | | | $ | 566 | |
| Capacity revenue | | 451 | | | — | | | — | | | 451 | |
| Operating revenue | | $ | 461 | | | $ | 554 | | | $ | 2 | | | $ | 1,017 | |
Minimum future rent payments for the remaining periods related to the Conventional segment operating leases as of December 31, 20212022 were as follows:
| | | (In millions) | | (In millions) |
| 2022 | $ | 453 | | |
| 2023 | 2023 | 261 | | 2023 | $ | 261 | |
| 2024 | 2024 | 106 | | 2024 | 106 | |
| 2025 | 2025 | 107 | | 2025 | 107 | |
| 2026 | 2026 | 108 | | 2026 | 108 | |
| 2027 | | 2027 | 109 | |
| Thereafter | Thereafter | 1,390 | | Thereafter | 1,281 | |
| Total lease payments | Total lease payments | $ | 2,425 | | Total lease payments | $ | 1,972 | |
Property, plant and equipment, net related to the Company’s operating leases were as follows:
| | (In millions) | (In millions) | December 31, 2021 | | December 31, 2020 | (In millions) | December 31, 2022 | | December 31, 2021 |
| Property, plant and equipment | Property, plant and equipment | $ | 8,981 | | | $ | 7,201 | | Property, plant and equipment | $ | 8,630 | | | $ | 8,981 | |
| Accumulated depreciation | Accumulated depreciation | (2,827) | | | (1,964) | | Accumulated depreciation | (2,855) | | | (2,827) | |
| Net property, plant and equipment | Net property, plant and equipment | $ | 6,154 | | | $ | 5,237 | | Net property, plant and equipment | $ | 5,775 | | | $ | 6,154 | |
Schedule I
Clearway Energy LLC (Parent)
Condensed Financial Information of Registrant
Condensed Statements of OperationsIncome
| | | | | | | | | | | | | | | | | |
| Year ended December 31, |
| (In millions) | 2021 | | 2020 | | 2019 |
| | | | | |
| Equity in earnings (losses) of consolidated affiliates | $ | 110 | | | $ | 61 | | | $ | (32) | |
| | | | | |
| Other income, net | — | | | — | | | 2 | |
| | | | | |
| | | | | |
| Total other income, net | — | | | — | | | 2 | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| Net Income (Loss) Attributable to Clearway Energy LLC | $ | 110 | | | $ | 61 | | | $ | (30) | |
| | | | | | | | | | | | | | | | | |
| Year ended December 31, |
| (In millions) | 2022 | | 2021 | | 2020 |
| Total operating costs and expenses | $ | 1 | | | $ | — | | | $ | — | |
| Equity in earnings of consolidated affiliates | 1,379 | | | 110 | | | 61 | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| Interest income | 10 | | | — | | | — | |
| Total other income | 1,389 | | | 110 | | | 61 | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| Net Income Attributable to Clearway Energy LLC | $ | 1,388 | | | $ | 110 | | | $ | 61 | |
See accompanying notes to condensed financial statements.
Schedule I
Clearway Energy LLC (Parent)
Condensed Balance Sheets | | | | | | | | | | | |
| December 31, | | December 31, |
| 2021 | | 2020 |
| ASSETS | (In millions) |
| Current Assets | | | |
| Cash and cash equivalents | $ | 33 | | | $ | 119 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Investment in consolidated subsidiaries | 1,497 | | | 1,545 | |
| | | |
| | | |
| | | |
| | | |
| Total Assets | $ | 1,530 | | | $ | 1,664 | |
| LIABILITIES AND MEMBERS' EQUITY | | | |
| Current Liabilities | | | |
| | | |
| | | |
| Accounts payable — affiliates | $ | 5 | | | $ | 24 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Total Liabilities | 5 | | | 24 | |
| Commitments and Contingencies | | | |
| Members' Equity | | | |
| Contributed capital | 1,495 | | | 1,723 | |
| Retained earnings (Accumulated deficit) | 43 | | | (50) | |
| Accumulated other comprehensive loss | (13) | | | (33) | |
| | | |
| Total Members' Equity | 1,525 | | | 1,640 | |
| Total Liabilities and Members’ Equity | $ | 1,530 | | | $ | 1,664 | |
| | | | | | | | | | | |
| December 31, | | December 31, |
| 2022 | | 2021 |
| ASSETS | (In millions) |
| Current Assets | | | |
| Cash and cash equivalents | $ | 536 | | | $ | 33 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Other current assets | 1 | | | — | |
| | | |
| Other Assets | | | |
| Investment in consolidated subsidiaries | 2,034 | | | 1,497 | |
| | | |
| | | |
| | | |
| | | |
| Total Assets | $ | 2,571 | | | $ | 1,530 | |
| LIABILITIES AND MEMBERS’ EQUITY | | | |
| Current Liabilities | | | |
| | | |
| | | |
| Accounts payable — affiliates | $ | 1 | | | $ | 5 | |
| | | |
| | | |
| | | |
| Other Liabilities | | | |
| | | |
| | | |
| | | |
| Other non-current liabilities | 1 | | | — | |
| Total Liabilities | 2 | | | 5 | |
| Commitments and Contingencies | | | |
| Members’ Equity | | | |
| Contributed capital | 1,308 | | | 1,495 | |
| Retained earnings | 1,240 | | | 43 | |
| Accumulated other comprehensive income (loss) | 21 | | | (13) | |
| | | |
| Total Members’ Equity | 2,569 | | | 1,525 | |
| Total Liabilities and Members’ Equity | $ | 2,571 | | | $ | 1,530 | |
See accompanying notes to condensed financial statements.
Schedule I
Clearway Energy LLC (Parent)
Condensed Statements of Cash Flows
| | | Years ended December 31, | | Years ended December 31, |
| | 2021 | | 2020 | | 2019 | | 2022 | | 2021 | | 2020 |
| | (In millions) | | (In millions) |
| Cash Flows from Operating Activities | Cash Flows from Operating Activities | | Cash Flows from Operating Activities | |
| Net Cash Provided by Operating Activities | Net Cash Provided by Operating Activities | $ | — | | | $ | — | | | $ | — | | Net Cash Provided by Operating Activities | $ | 8 | | | $ | — | | | $ | — | |
| Cash Flows from Investing Activities | Cash Flows from Investing Activities | | Cash Flows from Investing Activities | |
| Investments in consolidated affiliates | Investments in consolidated affiliates | 202 | | | 306 | | | (211) | | Investments in consolidated affiliates | 845 | | | 202 | | | 306 | |
| | Net Cash Provided by (Used in) Investing Activities | 202 | | | 306 | | | (211) | | |
| Net Cash Provided by Investing Activities | | Net Cash Provided by Investing Activities | 845 | | | 202 | | | 306 | |
| Cash Flows from Financing Activities | Cash Flows from Financing Activities | | Cash Flows from Financing Activities | |
| Transfer of funds under intercompany cash management arrangement | Transfer of funds under intercompany cash management arrangement | (20) | | | (65) | | | (5) | | Transfer of funds under intercompany cash management arrangement | (42) | | | (20) | | | (65) | |
| | Proceeds from issuance of Class C units | Proceeds from issuance of Class C units | — | | | 62 | | | 100 | | Proceeds from issuance of Class C units | — | | | — | | | 62 | |
| | Tax-related distributions | | Tax-related distributions | (19) | | | — | | | — | |
| Payments of distributions | Payments of distributions | (268) | | | (211) | | | (155) | | Payments of distributions | (289) | | | (268) | | | (211) | |
| Net Cash Used in Financing Activities | Net Cash Used in Financing Activities | (288) | | | (214) | | | (60) | | Net Cash Used in Financing Activities | (350) | | | (288) | | | (214) | |
| Net (Decrease) Increase in Cash and Cash Equivalents | (86) | | | 92 | | | (271) | | |
| Net Increase (Decrease) in Cash and Cash Equivalents | | Net Increase (Decrease) in Cash and Cash Equivalents | 503 | | | (86) | | | 92 | |
| Cash and Cash Equivalents at Beginning of Period | Cash and Cash Equivalents at Beginning of Period | 119 | | | 27 | | | 298 | | Cash and Cash Equivalents at Beginning of Period | 33 | | | 119 | | | 27 | |
| Cash and Cash Equivalents at End of Period | Cash and Cash Equivalents at End of Period | $ | 33 | | | $ | 119 | | | $ | 27 | | Cash and Cash Equivalents at End of Period | $ | 536 | | | $ | 33 | | | $ | 119 | |
|
See accompanying notes to condensed financial statements.
Schedule I
Clearway Energy LLC (Parent)
Notes to Condensed Financial Statements
Note 1 — Background and Basis of Presentation
Background
Clearway Energy LLC, together with its consolidated subsidiaries, or the Company, is an energy infrastructure investor with a focus on investments in clean energy and owner of modern, sustainable and long-term contracted assets across North America. The Company is sponsored by GIP and TotalEnergies through the portfolio company, Clearway Energy Group LLC, or CEG, which became equally owned by GIP and TotalEnergies as of September 12, 2022, when TotalEnergies acquired, through its portfolioinvestment in an intermediate holding company, 50% of GIP’s interest in CEG. 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.
The Company is one of the largest renewable energy owners in the U.S. with over 5,0005,500 net MW of installed wind and solar generation projects. The Company'sCompany’s over 9,0008,000 net MW of assets includes approximately 2,500 net MW of environmentally-sound, highly efficient natural gas-fired generation facilities as well as the Thermal Business.facilities. Through this environmentally-sound, diversified and primarily contracted portfolio, the Company endeavors to increase distributions to its unit holders. The majoritySubstantially all of the Company's generation assetsCompany’s revenues are underderived from long-term contractual arrangements for the output or capacity from these assets.
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.
Clearway Energy, Inc., or Clearway, Inc., consolidates the results of Clearway Energy LLC through its controlling interest, with CEG'sCEG’s interest shown as noncontrolling interest in the financial statements. The holders of Clearway, Inc.'s’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 Clearway Inc’s Class A and/or Class C common stock.
As of December 31, 2021,2022, Clearway, Inc. owned 57.65%57.88% of the economic interests of the Company, with CEG owning 42.35%42.12% of the economic interests of the Company. For further discussion, see Note 11, Members'Members’ Equity.
Basis of Presentation
The condensed parent-only company financial statements have been prepared in accordance with Rule 12-04 of Regulation S-X, as the restricted net assets of Clearway Energy LLC'sLLC’s subsidiaries exceed 25% of the consolidated net assets of Clearway Energy LLC. The parent'sparent’s 100% investment in its subsidiaries has been recorded using the equity basis of accounting in the accompanying condensed parent-only financial statements. These statements should be read in conjunction with the consolidated financial statements and notes thereto of Clearway Energy LLC.
Note 2 — Long-Term Debt
For a discussion of Clearway Energy LLC’s financing arrangements, see Note 10, Long-term Debt, to the Company'sCompany’s consolidated financial statements.
Note 3 — Commitments, Contingencies and Guarantees
See Note 14, Commitments and Contingencies, to the Company'sCompany’s consolidated financial statements for a detailed discussion of Clearway Energy LLC’s commitments and contingencies.
Note 4 — Distributions
Cash distributions paid on the Company'sCompany’s Class A, Class B, Class C and Class D units, were $289 million, $268 million, $211 million, and $155$211 million for the years ended December 31, 2022, 2021, 2020, and 2019,2020, respectively.
EXHIBIT INDEX | | | | | | | | | | | | | | | | | |
| Number | | Description | | Method of Filing | |
2.1* | | | | Incorporated herein by reference to Exhibit 2.10 to Clearway Energy, Inc.'s Annual Report on Form 10-K filed on March 1, 2018. | |
2.2* | | | | Incorporated herein by reference to Exhibit 2.1 to the Company's Current Report on Form 8-K, filed on December 9, 2019. | |
| 2.3 | | | | Incorporated herein by reference to Exhibit 2.1 to the Company'sCompany’s Current Report on Form 8-K filed on November 20, 2020. | |
| 3.1 | | | | Incorporated herein by reference to Exhibit 3.01(a) to the Company'sCompany’s Registration Statement on Form S-4 filed on April 13, 2015. | |
| 3.2 | | | | Incorporated herein by reference to Exhibit 3.01(b) to the Company'sCompany’s Registration Statement on Form S-4 filed on April 13, 2015. | |
| 3.3 | | | | Incorporated herein by reference to Exhibit 3.3. to the Company'sCompany’s Annual Report on Form 10-K filed on February 28, 2019. | |
| 3.4 | | | | Incorporated herein by reference to Exhibit 3.03(a) to the Company'sCompany’s Registration Statement on Form S-4 filed on April 13, 2015. | |
| 3.5 | | | | Incorporated herein by reference to Exhibit 3.03(b) to the Company'sCompany’s Registration Statement on Form S-4 filed on April 13, 2015. | |
| 3.6 | | | | Incorporated herein by reference to Exhibit 10.6 to Clearway Energy, Inc.'s’s Current Report on Form 8-K filed on September 5, 2018. | |
| 4.1 | | | | Incorporated herein by reference to Exhibit 4.1 to the Company'sCompany’s Current Report on Form 8-K filed on December 12, 2019. | |
| 4.2 | | | | Incorporated herein by reference to Exhibit 4.1 to the Company'sCompany’s Current Report on Form 8-K filed on December 12, 2019. | |
| 4.3 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on January 8, 2020. | |
| 4.4 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on March 3, 2020. | |
| 4.5 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company'sCompany’s Current Report on Form 8-K filed on July 21, 2020. | |
| 4.6 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company'sCompany’s Current Report on Form 8-K filed on August 20, 2020. | |
| 4.7 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company'sCompany’s Current Report on Form 8-K filed on November 19, 2020. | |
| 4.8 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company'sCompany’s Current Report on Form 8-K filed on December 4, 2020. | |
| 4.9 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company'sCompany’s Current Report on Form 8-K filed on December 29, 2020. | |
| 4.10 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company'sCompany’s Current Report on Form 8-K filed on February 5, 2021. | |
| 4.11 | | | | Incorporated herein by reference to Exhibit 4.1 to the Company'sCompany’s Current Report on Form 8-K filed on March 9, 2021. | |
| 4.12 | | | | Incorporated herein by reference to Exhibit 4.2 to the Company'sCompany’s Current Report on Form 8-K filed on March 9, 2021. | |
| | | | | | | | | | | | | | | | | |
| 4.13 | | | | Incorporated herein by reference to Exhibit 4.2 to the Company'sCompany’s Current Report on Form 8-K filed on May 19, 2021. | |
| 4.14 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company'sCompany’s Current Report on Form 8-K filed on May 19, 2021. |
| | | | | | | | | | | | | | |
| 4.15 | | | | Incorporated herein by reference to Exhibit 4.1 to the Company'sCompany’s Current Report on Form 8-K filed on October 1, 2021. | |
| 4.16 | | | | Incorporated herein by reference to Exhibit 4.2 to the Company'sCompany’s Current Report on Form 8-K filed on October 1, 2021. | |
| 4.17 | | | | Incorporated herein by reference to Exhibit 4.2 to the Company'sCompany’s Current Report on Form 8-K filed on October 8, 2021. | |
| 4.18 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company'sCompany’s Current Report on Form 8-K filed on October 8, 2021. | |
| 4.19 | | | | Incorporated herein by reference to Exhibit 4.4 to the Company'sCompany’s Current Report on Form 8-K filed on October 8, 2021. |
| 4.20 | | | | Incorporated herein by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on June 1, 2022. |
| 4.21 | | | | Incorporated herein by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K filed on June 1, 2022. |
| 4.22 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on June 1, 2022. |
| 4.23 | | | | Incorporated herein by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on February 21, 2023. |
| 4.24 | | | | Incorporated herein by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K filed on February 21, 2023. |
| 4.25 | | | | Incorporated herein by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on February 21, 2023. |
| 10.1 | | | | Incorporated herein by reference to Exhibit 10.5 to Clearway Energy, Inc.'s’s Current Report on Form 8-K filed on September 5, 2018. | |
| 10.2.1 | | | | Incorporated herein by reference to Exhibit 10.3 to Clearway Energy, Inc.'s’s Current Report on Form 8-K filed on September 5, 2018. | |
| 10.2.2 | | | | Incorporated herein by reference to Exhibit 10.1 to Clearway Energy, Inc.'s’s Current Report on Form 8-K filed on February 14, 2019. | |
| 10.2.3 | | | | Incorporated herein by reference to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q filed on August 6, 2019. | |
| 10.2.4 | | | | Incorporated herein by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on December 9, 2019. | |
| 10.3 | | | | Incorporated herein by reference to Exhibit 10.1 to Clearway Energy, Inc.'s’s Current Report on Form 8-K filed on September 5, 2018. | |
| 10.4 | | | | Incorporated herein by reference to Exhibit 10.2 to Clearway Energy, Inc.'s’s Current Report on Form 8-K filed on September 5, 2018. | |
| 10.5 | | | | Incorporated herein by reference to Exhibit 10.9 to Clearway Energy, Inc.'s’s Current Report on Form 8-K filed on September 5, 2018. | |
| 10.6.1 | | Amended and Restated Credit Agreement, dated April 25, 2014, by and among NRG Yield Operating LLC, NRG Yield LLC, Royal Bank of Canada, as Administrative Agent, the lenders party thereto, Royal Bank of Canada, Goldman Sachs Bank USA and Bank of America, N.A., as L/C Issuers and RBC Capital Markets as Sole Left Lead Arranger and Sole Left Lead Book Runner. | | Incorporated by reference to Exhibit 10.1 to Clearway Energy, Inc.'s’s Current Report on Form 8-K filed on April 28, 2014. | |
| 10.6.2 | | | | Incorporated herein by reference to Exhibit 10.9 to Clearway Energy, Inc.'s’s Quarterly Report on Form 10-Q filed on August 4, 2015. |
| | | | | | | | | | | | | | |
| 10.6.3 | | | | Incorporated herein by reference to Exhibit 10.1 to the Company'sCompany’s Current Report on Form 8-K filed on February 12, 2018.
| |
| 10.6.4 | | Third Amendment to Amended and Restated Credit Agreement and Administrative Agent Resignation and Appointment Agreement, dated as of April 30, 2018, by and among NRG Yield Operating LLC, NRG Yield LLC, the guarantors party thereto, Royal Bank of Canada, as Resigning Administrative Agent, JPMorgan Chase Bank, N.A., as Successor Administrative Agent, and the lenders party thereto. | | Incorporated herein by reference to Exhibit 10.1 to the Company'sCompany’s Quarterly Report on Form 10-Q filed on May 3, 2018.
| |
| | | | | | | | | | | | | | | | | |
| 10.6.5 | |
| | Incorporated herein by reference to Exhibit 10.1 to the Company'sCompany’s Current Report on Form 8-K filed on December 6, 2018.
| |
| 10.6.6 | |
| | Incorporated herein by reference to Exhibit 10.1 to the Company'sCompany’s Current Report on Form 8-K filed on December 23, 2019.
| |
| 10.6.7 | | | | Incorporated herein by reference to Exhibit 10.1 to the Company'sCompany’s Current Report on Form 8-K filed on December 1, 2021. |
| 10.6.8 | | | | Incorporated herein by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on August 19, 2022. |
| 10.7^ | | | | Incorporated herein by reference to Exhibit 10.1 to Clearway Energy, Inc.'s’s Quarterly Report on Form 10-Q filed on August 4, 2015. | |
| 10.8^ | | | | Incorporated herein by reference to Exhibit 10.2 to Clearway Energy, Inc.'s’s Quarterly Report on Form 10-Q filed on August 4, 2015. | |
| 10.9^ | | | | Incorporated herein by reference to Exhibit 10.1 to Clearway Energy, Inc.'s’s Quarterly Report on Form 10-Q filed on May 5, 2016.
| |
| 10.10^ | | | | Incorporated herein by reference to Exhibit 10.2 to Clearway Energy, Inc.'s’s Quarterly Report on Form 10-Q filed on May 5, 2016.
| |
| 10.11^ | | | | Incorporated herein by reference to Exhibit 10.3 to Clearway Energy, Inc.'s’s Quarterly Report on Form 10-Q filed on May 5, 2016. | |
| 10.12 | | | | Incorporated herein by reference to Exhibit 10.1 to Clearway Energy, Inc.'s’s Quarterly Report on Form 10-Q, filed on August 9, 2016.
| |
| 10.13 | | | | Incorporated herein by reference to Exhibit 10.30 to the Company'sCompany’s Annual Report on Form 10-K filed on February 28, 2019. | |
| 10.14 | | Amended and Restated Exchange Agreement, dated as of May 14, 2015, by and among NRG Energy, Inc., NRG Yield, Inc., and NRG Yield LLC and, pursuant to a joinder thereto, dated as of August 31, 2018, Zephyr Renewables LLC. | | Incorporated herein by reference to Exhibit 10.1 to Clearway Energy, Inc.'s’s Current Report on Form 8-K filed on May 15, 2015. | |
| 10.15† | | | | Incorporated herein by reference to Exhibit 10.26 to the Clearway Energy, Inc. Annual Report on Form 10-K filed on March 2, 2020. | |
| 10.16† | | | | Incorporated by reference to Exhibit 10.19 to the Company'sCompany’s Annual Report on Form 10-K, filed on March 1, 2021. | |
| 10.17† | | | | Incorporated by reference to Exhibit 10.20 to the Company'sCompany’s Annual Report on Form 10-K, filed on March 1, 2021. |
| | | | | | | | | | | | | | |
| 10.18*^ | | | | Incorporated herein by reference to Exhibit 10.1 to the Company'sCompany’s Current Report on Form 8-K filed on April 20, 2020. | |
| 10.19*^ | | | | Incorporated herein by reference to Exhibit 10.2 to the Company'sCompany’s Current Report on Form 8-K filed on April 20, 2020. | |
| 10.20*^ | | | | Incorporated herein by reference to Exhibit 10.3 to the Company'sCompany’s Current Report on Form 8-K filed on April 20, 2020. | |
| 10.21 | | | | Incorporated herein by reference to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q filed on November 5, 2020. | |
| | | | | | | | | | | | | | | | | |
| 10.22†* | | | | Incorporated herein by reference to Exhibit 10.1 to the Company'sCompany’s Current Report on Form 8-K filed on December 22, 2020. | |
| 10.23†* | | | | Incorporated herein by reference to Exhibit 10.2 to the Company'sCompany’s Current Report on Form 8-K filed on December 22, 2020. | |
| 10.24†* | | | | Incorporated herein by reference to Exhibit 10.3 to the Company'sCompany’s Current Report on Form 8-K filed on December 22, 2020. | |
| 10.25*^ | | | | Incorporated by reference to Exhibit 10.31 to the Company'sCompany’s Annual Report on Form 10-K, filed on March 1, 2021. | |
| 10.26 | | | | Incorporated by reference to Exhibit 10.2 to the Company'sCompany’s Quarterly Report on Form 10-Q, filed on August 3, 2021. | |
| 10.27 | | | | Incorporated by reference to Exhibit 10.1 to the Company'sCompany’s Current Report on Form 8-K, filed on August 23, 2021. | |
| 10.28 | | | | Incorporated by reference to Exhibit 10.1 to the Company'sCompany’s Current Report on Form 8-K, filed on September 23, 2021. | |
| 10.29 | | | | Incorporated by reference to Exhibit 10.1 to the Company'sCompany’s Current Report on Form 8-K, filed on October 26, 2021. | |
| 10.30 | | | | Incorporated by reference to Exhibit 10.2 to the Company'sCompany’s Current Report on Form 8-K, filed on December 1, 2021. | |
| 10.31*^ | | | | Incorporated herein by reference to Exhibit 10.1 to the Company'sCompany’s Current Report on Form 8-K filed on January 18, 2022. | |
| 10.32*^ | | | | Incorporated herein by reference to Exhibit 10.2 to the Company'sCompany’s Current Report on Form 8-K filed on January 18, 2022. |
| 10.33† | | | | Incorporated herein by reference to Exhibit 10.3 to the Company’s Quarterly Report on Form 10-Q filed on May 5, 2022. |
| 10.34† | | | | Incorporated herein by reference to Exhibit 10.4 to the Company’s Quarterly Report on Form 10-Q filed on May 5, 2022. |
| 10.35† | | | | Incorporated herein by reference to Exhibit 10.5 to the Company’s Quarterly Report on Form 10-Q filed on May 5, 2022. |
| 10.36† | | | | Incorporated herein by reference to Exhibit 10.6 to the Company’s Quarterly Report on Form 10-Q filed on May 5, 2022. |
| 10.37† | | | | Incorporated herein by reference to Exhibit 10.7 to the Company’s Quarterly Report on Form 10-Q filed on May 5, 2022. |
| 10.38*^ | | | | Incorporated herein by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on December 29, 2022. |
| | | | | | | | | | | | | | |
| 10.39 | | | | Filed herewith. |
| 10.40 | | | | Filed herewith. |
| 16.1 | | | | Incorporated herein by reference to Exhibit 16.1 to the Company’s Current Report on Form 8-K filed on March 15, 2021. | |
| 21.1 | | | | Filed herewith. | |
| 24.1 | | | | Included on the signature page of this Annual Report on Form 10-K. | |
| 31.1 | | | | Filed herewith. | |
| 31.2 | | | | Filed herewith. | |
31.3 | | | | Filed herewith. | |
| 32 | | | | Furnished herewith. | |
| 101 INS | | Inline XBRL Instance Document. | | Filed herewith. | |
| 101 SCH | | Inline XBRL Taxonomy Extension Schema. | | Filed herewith. | |
| 101 CAL | | Inline XBRL Taxonomy Extension Calculation Linkbase. | | Filed herewith. | |
| 101 DEF | | Inline XBRL Taxonomy Extension Definition Linkbase. | | Filed herewith. | |
| 101 LAB | | Inline XBRL Taxonomy Extension Label Linkbase. | | Filed herewith. | |
| 101 PRE | | Inline XBRL Taxonomy Extension Presentation Linkbase. | | Filed herewith. | |
| 104 | | Cover Page Interactive Data File (the cover page interactive data file does not appear in Exhibit 104 because its Inline XBRL tags are embedded within the Inline XBRL document) | | | |
| | | | | | | | |
| † | | Indicates exhibits that constitute compensatory plans or arrangements. |
| * | | This filing excludes schedules pursuant to Item 601(a)(5) of Regulation S-K, which the registrant agrees to furnish supplementary to the Securities and Exchange Commission upon request by the Commission. |
| ^ | | Information in this exhibit identified by the mark “[***]” is confidential and has been excluded pursuant to Item 601(b)(10)(iv) of Regulation S-K because it (i) is not material and (ii) would likely cause competitive harm to the Registrant if disclosed.
|
Item 16 — Form 10-K Summary
None.
SIGNATURES
Pursuant to the requirements of Section 13 or 15 (d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| | | | | | | | | | | | | | |
| | CLEARWAY ENERGY LLC
(Registrant) | |
| | |
| | /s/ CHRISTOPHER S. SOTOS | |
| | Christopher S. Sotos | |
| | Chief Executive Officer (Principal Executive Officer) | |
| |
Date: February 25, 202223, 2023 | | |
| |
POWER OF ATTORNEY
Each person whose signature appears below constitutes and appoints Christopher S. Sotos, Kevin P. Malcarney and Amelia McKeithen, each or any of them, such person'sperson’s true and lawful attorney-in-fact and agent with full power of substitution and resubstitution for such person and in such person'sperson’s name, place and stead, in any and all capacities, to sign any and all amendments to this report on Form 10-K, and to file the same with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing necessary or desirable to be done in and about the premises, as fully to all intents and purposes as such person, hereby ratifying and confirming all that said attorneys-in-fact and agents, or any of them or his or their substitute or substitutes, may lawfully do or cause to be done by virtue hereof.
In accordance with the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
| | | | | | | | | | | | | | |
| Signatures | | Title | |
| /s/ CHRISTOPHER S. SOTOS | | President and Chief Executive Officer | |
| Christopher S. Sotos | | of Clearway Energy LLC (Principal Executive Officer) | |
| Date: | February 25, 202223, 2023 | | | |
| | | | |
| /s/ CHAD PLOTKIN | | Executive Vice President and Chief Financial Officer | |
| Chad Plotkin | | of Clearway Energy LLC (Principal Financial Officer) | |
Date: | February 25, 2022 | | | |
| | | | |
| /s/ SARAH RUBENSTEIN | | Senior Vice President and Chief Accounting Officer | |
| Sarah Rubenstein | | of Clearway Energy LLC (Principal Accounting Officer)Financial and | |
| Date: | February 25, 202223, 2023 | | Principal Accounting Officer) | |
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| CLEARWAY ENERGY, INC. | | Sole Managing Member | |
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| /s/ CHRISTOPHER S. SOTOS | | President and Chief Executive Officer | |
| Christopher S. Sotos | | of Clearway Energy, Inc. | |
| Date: | February 25, 202223, 2023 | | | |
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| Signature | | Title | | Date |
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| /s/ NATHANIEL ANSCHUETZ | | Director of Clearway Energy, Inc. | | February 25, 202223, 2023 |
| Nathaniel Anschuetz | | Sole Managing Member of Clearway Energy LLC | |
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| /s/ JONATHAN BRAM | | Director of Clearway Energy, Inc. | | February 25, 202223, 2023 |
| Jonathan Bram | | Sole Managing Member of Clearway Energy LLC | |
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| /s/ BRIAN FORD | | Director of Clearway Energy, Inc. | | February 25, 202223, 2023 |
| Brian Ford | | Sole Managing Member of Clearway Energy LLC | |
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| /s/ BRUCE MACLENNAN | | Director of Clearway Energy, Inc. | | February 25, 202223, 2023 |
| Bruce MacLennan | | Sole Managing Member of Clearway Energy LLC | |
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/s/ FERRELL MCCLEAN | | Director of Clearway Energy, Inc. | | February 25, 2022 |
Ferrell McClean | | Sole Managing Member of Clearway Energy LLC | |
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| /s/ DANIEL B. MORE | | Director of Clearway Energy, Inc. | | February 25, 202223, 2023 |
| Daniel B. More | | Sole Managing Member of Clearway Energy LLC | |
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/s/ E. STANLEY O'NEALO’NEAL | | Director of Clearway Energy, Inc. | | February 25, 202223, 2023 |
E. Stanley O'NealO’Neal | | Sole Managing Member of Clearway Energy LLC | |
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| /s/ GUILLAUME HÉDIARD | | Director of Clearway Energy, Inc. | | February 23, 2023 |
| Guillaume Hédiard | | Sole Managing Member of Clearway Energy LLC | |
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| /s/ VINCENT STOQUART | | Director of Clearway Energy, Inc. | | February 23, 2023 |
| Vincent Stoquart | | Sole Managing Member of Clearway Energy LLC | |
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| /s/ EMMANUEL BARROIS | | Director of Clearway Energy, Inc. | | February 23, 2023 |
| Emmanuel Barrois | | Sole Managing Member of Clearway Energy LLC | |
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| /s/ CHRISTOPHER S. SOTOS | | Director of Clearway Energy, Inc. | | February 25, 202223, 2023 |
| Christopher S. Sotos | | Sole Managing Member of Clearway Energy LLC | |
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| /s/ JENNIFER LOWRY | | Director of Clearway Energy, Inc. | | February 23, 2023 |
| Jennifer Lowry | | Sole Managing Member of Clearway Energy LLC | |
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Supplemental Information to be Furnished with Reports Filed Pursuant to Section 15(d) of the Act by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Act
No annual report or proxy materials has been sent to securities holders and no such report or proxy material is to be furnished to securities holders subsequent to the filing of the annual report on this Form 10-K.
