Clearway Energy, Inc. (CWEN) Business

Item 1 — Business

General

Clearway Energy, Inc., together with its consolidated subsidiaries, or the Company, is a publicly-traded energy infrastructure investor with a focus on investments in clean energy and owner of modern, sustainable and long-term contracted assets across North America. The Company was formed as a Delaware corporation on December 20, 2012. The Company is sponsored by Clearway Energy Group LLC, or CEG.

The Company is one of the largest owners of clean energy generation assets in the U.S. The Company’s portfolio comprises approximately 12.9 GW of gross capacity in 27 states, including approximately 10.1 GW of wind, solar and battery energy storage systems, or BESS, and approximately 2.8 GW of dispatchable combustion-based power generation assets included in the Flexible Generation segment that provide critical grid reliability services. In 2025, 98% of the Company’s total generation was attributable to renewable energy and storage assets. Through this environmentally-sound, diversified and primarily contracted portfolio, the Company endeavors to provide its investors with stable and growing dividend income. The majority of the Company’s revenues are derived from long-term contractual arrangements for the output or capacity from these assets. The weighted average remaining contract duration of the Company’s Renewables & Storage segment offtake agreements was approximately 12 years as of December 31, 2025 based on CAFD. A complete listing of the Company’s interests in operating facilities as of December 31, 2025 can be found in Item 2 — Properties.

The Company is the sole managing member of Clearway Energy LLC and operates and controls all of its business and affairs and consolidates the financial results of Clearway Energy LLC and its subsidiaries. Clearway Energy LLC is a holding company for the companies that directly and indirectly own and operate the Company’s assets. The Company consolidates the results of Clearway Energy LLC through its controlling interest, with CEG’s interest shown as noncontrolling interest in the consolidated financial statements. The holders of the Company’s outstanding shares of Class A and Class C common stock are entitled to dividends as declared. CEG receives its distributions from Clearway Energy LLC through its ownership of Clearway Energy LLC Class B and Class D units. As a result of its current ownership of the Class B common stock and Class D common stock of the Company, CEG controls the Company. From time to time, CEG may also hold shares of the Company’s Class A and/or Class C common stock.

As of December 31, 2025, the Company owned 58.62% of the economic interests of Clearway Energy LLC, with CEG owning 41.38% of the economic interests of Clearway Energy LLC.

6

The diagram below represents a summarized structure of the Company as of December 31, 2025:

Business Strategy

The Company’s primary business strategy is to focus on the ownership of assets and growth through investments in or acquisitions of assets that generate predictable, long-term cash flows so that it can continue to grow and expand the business as well as to increase the dividends paid to holders of the Company’s Class A and Class C common stock over time.

The Company’s plan for executing its business strategy includes the following key components:

Focus on contracted renewable energy and dispatchable combustion-based generation. The Company owns and operates utility scale and distributed renewable energy assets, as well as BESS facilities, and dispatchable combustion-based power generation assets included in the Flexible Generation segment that provide critical grid reliability services. The assets are operated with proven technologies and have generally low operating risks and stable cash flows. The Company believes that 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.

7

Growing the business through investments in operating power generation assets. The Company believes that its base of operations provides a platform for strategic growth through cash accretive and tax advantaged investments and acquisitions complementary to its existing portfolio and investment in organic cash flow expansion of its own fleet. In addition, the Company may invest in or acquire generation facilities from third parties when it believes its knowledge of the market and operating expertise provides it with a competitive advantage, as well as consummate future investments in, or acquisitions of, assets developed by CEG. The Company believes that CEG’s development expertise provides the Company access to a development platform with an extensive pipeline of potential renewable energy and BESS facilities that are aligned with the Company’s growth objectives. The Company and CEG work collaboratively in considering new assets to be invested in or acquired by the Company. The assets listed below represent the Company’s currently committed investments in facilities:

(a) Third-party acquisition of operating facilities.

(b) Included in a co-investment partnership.

Primary focus on North America. The Company intends to focus its investments in North America. The Company believes that industry fundamentals in North America offer significant opportunity to grow its portfolio without creating significant exposure to currency or sovereign risk. By 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 its performance.

Maintain sound financial practices to grow the dividend. The Company intends to maintain a commitment to disciplined financial analysis and a balanced capital structure to enable it to increase its quarterly dividend over time and serve the long-term interests of its stockholders. The Company’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 long-term dividends and maximize value; and a dividend policy that is based on distributing a significant portion of CAFD each quarter that the Company receives from Clearway Energy LLC, subject to available capital, market conditions and compliance with associated laws, regulations and other contractual obligations.

Competition

Power generation is a capital-intensive business with numerous and diverse industry participants. The Company competes based on the location of its plants, as well as the contract price and terms of individual facilities. Within the power industry, the Company competes with a wide variety of companies with different capabilities, resources and business models, depending on the market. The Company’s competitors for energy supply include utilities and independent power producers. The Company also competes to acquire new facilities with renewable developers who retain ownership of their renewable power plants, independent power producers, financial investors and other downstream power infrastructure owners. Competitive conditions may be substantially affected by capital market conditions and by various forms of energy-related legislation and regulation considered by federal, state and local legislatures and administrative agencies, including tax policy. Such laws and regulations, or changes thereto, may substantially increase the costs of acquiring, constructing and operating facilities, and it could be difficult for the Company to adapt to and operate under such laws and regulations.

8

Competitive Strengths

Stable, high quality cash flows. The Company’s facilities have a stable, predictable cash flow profile consisting of 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 majority of the Company’s facilities have minimal fuel risk, as the Renewables & Storage facilities have no fuel costs, however, the Company’s merchant assets included in the Flexible Generation segment need to procure their own fuel. The offtake agreements within the Company’s Renewables & Storage segment have a weighted-average remaining duration, based on CAFD, of approximately 12 years as of December 31, 2025, which contributes to long-term cash flow stability. The Company’s offtake agreements with counterparties for whom credit ratings are available have a weighted-average Moody’s rating of Baa1 based on rated capacity under contract. Additionally, because all of the Company’s assets are located in the U.S., they are not exposed to currency or repatriation risks.

Environmentally well-positioned portfolio of assets. The Company’s portfolio includes approximately 10.1 gross GW of installed wind, solar and BESS assets that are predominantly non-emitting sources of power generation. Additionally, the Company’s assets within the Flexible Generation segment that are located in California consist of efficient gas generation facilities that support electric system reliability. The Company does not expect to incur 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 it will be a net beneficiary of growing energy demand and market support for the types of assets that the Company operates and acquires.

High quality, long-lived assets with low operating and capital requirements. The Company benefits from a portfolio of relatively newer assets. The Company’s assets are largely comprised of proven and reliable technologies, provided by leading original wind, solar and BESS equipment manufacturers. Given the nature of the portfolio, which includes a substantial number of wind, solar and BESS facilities, with relatively low operating and maintenance costs, the Company expects to maintain high fleet availability and expend modest maintenance-related capital expenditures.

Significant scale and diversity. The Company’s portfolio comprises approximately 12.9 GW of gross capacity in 27 states, including approximately 10.1 GW of wind, solar and BESS and approximately 2.8 GW of dispatchable combustion-based power generation providing critical grid reliability services. The Company’s contracted assets included in the Renewables & Storage and Flexible Generation segments benefit from significant diversification in terms of technology, fuel type, counterparty and geography. 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’s diversification reduces its operating risk profile and reliance on any single market.

Relationship with CEG as sponsor. The Company believes that its relationship with CEG provides significant benefits given CEG’s highly capable renewable development and operations platform that is aligned to support the Company’s growth. CEG has strong capabilities in capital formation, power origination, procurement, construction, business development, asset management, operations and maintenance and related commercial functions, all of which help to safeguard and optimize the value of the Company’s business and operating fleet.

Segment Review

The following tables summarize the Company’s operating revenues, net income (loss) and assets by segment, as discussed in Item 15 — Note 13, Segment Reporting:

9

Policy Incentives

U.S. federal, state and local governments have established various policy incentives to support the development, financing, ownership and operation of renewable energy facilities. These incentives include PTCs, ITCs, accelerated tax depreciation, cash grants, tax abatements and RPS programs which have the effect of decreasing the costs and risks associated with developing and operating such facilities 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, either the ITC or, in lieu thereof, a PTC, provided certain requirements are met. Additionally, owners of BESS 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. In order to qualify for the full amount of these credits in the case of facilities whose construction began on or after January 28, 2023, certain prevailing wage and apprenticeship requirements generally must be satisfied. 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 GHG emissions cannot be greater than zero. Moreover, pursuant to legislation enacted July 4, 2025, wind and solar facilities that begin construction after July 4, 2026 must be placed in service by December 31, 2027 in order to qualify for these credits and the percentage of components in the facility manufactured by foreign entities of concern cannot exceed a specified percentage.

•Pursuant to the U.S. federal Modified Accelerated Cost Recovery System, or MACRS, wind, solar and BESS facilities have generally been depreciable for tax purposes over a five-year period (before applying certain conventions), even though the useful life of such facilities is generally much longer than five years. However, pursuant to federal tax legislation enacted on July 4, 2025, in certain cases, facilities as to which construction begins after 2024 will no longer be depreciable over a five-year period; instead, their cost will be recovered over a seven-year period. Under the same legislation, immediate 100% expensing is also permanently available for such property.

•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, reduction in, or the addition of stricter eligibility requirements for the business tax credits and incentives discussed above could decrease the attractiveness of renewable energy facilities 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 facilities due to higher operating costs or decreased revenues under its PPAs. However, these changes (i) are not anticipated to have an adverse impact on the anticipated pipeline of facilities that are being developed by the Company’s sponsor, CEG, through at least 2030 and (ii) did not impact the operation of facilities owned by the Company.

10

Regulatory Matters

As owners of power plants and participants in wholesale energy markets, certain of the Company’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’s assets are located. Each of the Company’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’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’s reliability authority. The Company’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. Similarly, the Company’s operations within Hawaii are not subject to rate regulation by FERC, as they are deemed to operate solely within the State of Hawaii and not in interstate commerce.

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 and Hawaii 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 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’s QF generating facilities and all of the Company’s non-QF generating facilities located in the U.S. outside of ERCOT and Hawaii 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 and companies within the public utility holding company systems. The Company is not required to comply with the accounting, record retention and reporting requirements promulgated by FERC pursuant to 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, state and local environmental laws have historically become more stringent over time, although this trend has recently shifted at the federal level. To the extent that proposed legislation and new or revised regulations restrict or otherwise impact the Company’s operations, the proposed legislation and regulations could have a negative impact on the Company’s financial performance.

11

EPA GHG Rulemaking and Proposals — In March 2025, a Joint Resolution of Disapproval under the Congressional Review Act was signed which prohibited the EPA’s November 2024 Waste Emissions Charge rules from taking effect. Federal tax legislation enacted on July 4, 2025 postponed the EPA’s imposition of the Waste Emissions Charge to 2034. On July 29, 2025, the EPA issued an interim final rule extending several compliance deadlines associated with the strict new methane rules for the oil and gas industry that were published in March 2024 and took effect in May 2024. In December 2025, the EPA issued a final rule extending these compliance deadlines associated with its 2024 methane rules. On September 16, 2025, the EPA announced a proposal to end the Greenhouse Gas Reporting Program for all sectors except petroleum and natural gas systems (excluding reporting for natural gas distribution). Reporting for petroleum and natural gas systems under the Greenhouse Gas Reporting Program would be deferred until 2034 under the proposal. On February 12, 2026, the EPA announced the repeal of its 2009 “Endangerment Finding” under the Clean Air Act, which found that GHGs endanger the public health and welfare of current and future generations and emissions of GHGs from motor vehicles contribute to GHG pollution. The Endangerment Finding formed the EPA’s legal authority to regulate GHG emissions from motor vehicles, but the repeal calls into question the EPA’s authority to regulate GHGs not just from motor vehicles, but from all regulated sources, as well as the EPA’s prior scientific assessment of climate change risks. Litigation regarding the repeal is anticipated and it is unclear how the repeal will impact the EPA’s regulation of GHG emissions generally going forward. The move away from the federal regulation of GHGs and the repeal of the Endangerment Finding mark a significant shift in federal climate policy.

Changes to NEPA — In February 2025, the White House Council on Environmental Quality, or CEQ, sent NEPA Implementation Guidance to the heads of federal department and agencies to expedite and simplify the permitting process pursuant to Executive Order 14154, “Unleashing American Energy.” In the same month, CEQ issued an interim final rule removing its regulations implementing NEPA from the Code of Federal Regulations, which rule was finalized in January 2026. On May 29, 2025, the U.S. Supreme Court issued a decision in Seven County Infrastructure Coalition v. Eagle County, Colorado limiting the scope of upstream and downstream effects agencies must consider in NEPA reviews and clarifying that courts must afford agencies “substantial judicial deference” in NEPA cases. In July 2025, federal tax legislation added Section 112 to NEPA, which provides for expedited environmental reviews for a fee under NEPA, and the U.S. Army Corps of Engineers, FERC and the Departments of Energy, Interior, Transportation, Agriculture and Defense released updates to their regulations and procedures implementing NEPA to speed up permitting and streamline environmental reviews.

Federal Endangered Species Act Legislation and Regulations — In November 2025, the U.S. Fish and Wildlife Service proposed four rules, two of which were jointly issued with the National Marine Fisheries Service, which amend the federal Endangered Species Act, or ESA, regulations. The proposed rules revise the prior administration’s 2024 regulations under the ESA and revert to the 2019 and 2020 regulations regarding listing, delisting and critical habitat determinations, pursuant to Executive Order 14154, “Unleashing American Energy,” and the U.S. Department of Interior Secretary’s Order 3418 (implementing EO 14154).

Federal Eagle Incidental Take Permit Rule — On September 30, 2022, FWS published in the Federal Register a draft rule revising the eagle incidental take permit program. Comments on the revised rule continued to be accepted during 2023. The final eagle incidental take permit rule was published in the Federal Register on February 12, 2024, and became effective on April 13, 2024. The final rule provided expedited eagle take permitting and a lower cost pathway to permit issuance for many wind facilities but not all. Facility-specific permits will still be required for some facilities. In August 2025, DOI began auditing the eagle take permit program and eagle take permits for wind projects issued prior to January 2025 as part of the DOI’s implementation of Executive Order 14315 “Ending Market Distorting Subsidies for Unreliable, Foreign-Controlled Energy Sources” and DOI’s memorandum “Ensuring Compliance with the Bald and Gold Eagle Protection Act and Executive Order 14315.”

Federal MBTA Incidental Take Legislation and Regulations — On April 11, 2025, citing executive order “Unleashing American Energy,” the U.S. Department of the Interior, or DOI, issued a legal opinion repealing opinion M-37065, which was issued during the prior administration and specified that the MBTA prohibits both intentional and incidental take of migratory birds, and restoring opinion M-37050, which was issued during the first Trump administration and specifies that only intentional take of migratory birds is prohibited. On July 29, 2025, DOI announced a policy measure to review whether avian mortality rates associated with the development of wind energy facilities located in migratory flight paths qualify as “incidental” takings of birds under the MBTA and related laws, and to determine the appropriate approach to permitting these activities, identifying violations of the applicable statutes and related penalties.

12

California Climate Disclosure Laws — In September 2023, the California State Assembly passed landmark climate disclosure laws (SB 253 and SB 261, as amended by SB 219). These laws require large companies "doing business in California" to provide annual reporting of Scope 1, 2 and 3 GHG emissions to the state (SB 253) and the biennial disclosure of climate-related financial risks and mitigation (SB 261). The initial reporting of Scope 1 and 2 emissions under SB 253 is due August 10, 2026, and the reporting of Scope 3 emissions is set to begin in 2027. The biennial disclosure under SB 261 was originally due on January 1, 2026, however, on November 18, 2025, enforcement of SB 261 was stayed due to a preliminary injunction from the Ninth Circuit Court of Appeals. Litigation regarding both laws remains ongoing. The Company has prepared to comply with these new state requirements.

Local California Air District Rules — Air districts, including the San Diego Air Pollution Control District, have recently proposed and/or updated new source review permitting requirements, including to incorporate public notice requirements as well as updates to programs addressing toxic air contaminants. 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, cap and trade program in the next few years. The Company’s facilities in the Flexible Generation segment 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 facilities.

Customers

The Company sells its electricity and environmental attributes, including RECs, primarily to customers located across 27 states under contractual arrangements. The Company’s customer base includes 38 local utilities and 26 commercial and industrial customers delivered through its utility-scale generation fleet, as well as thousands of additional customers for products delivered from its distributed solar fleet. During the year ended December 31, 2025, the Company’s largest customers as a percentage of consolidated revenue were SCE and PG&E, which represented approximately 22% and 16%, respectively, with the next five largest customers representing a total of approximately 26% of consolidated revenue.

Human Capital

Effective January 1, 2025, the Company effected a reorganization pursuant to which all of the employees of the Company transferred to CEG. As a result, the Company does not have employees of its own and instead depends solely on the services provided by or under the direction of CEG under the CEG Master Services Agreement to carry out its operations. The Company directly bears all labor costs for certain employees of CEG who perform work on behalf of the Company. The Company also depends upon personnel of CEG for the provision of asset management, administration and O&M services.

In addition to the personnel of CEG, the Company relies on other third-party service providers in the daily operations of its facilities in the Flexible Generation segment, as well as certain renewable facilities.

The Company, together with CEG, focuses on attracting, developing and retaining a team of highly talented and motivated employees. CEG seeks to attract and retain employees with industry experience and relevant skills to support operations, which in certain areas requires specific professional or technical skills and experience. CEG’s programs to attract and recruit qualified candidates focus on identifying qualified candidates from a variety of backgrounds with the requisite skills and experience to bring value to the Company. CEG regularly conducts assessments of its compensation and benefit practices and pay levels to help ensure that staff members are compensated equitably and competitively. CEG devotes extensive resources to staff development and training, including tuition assistance for career-enhancing academic and professional programs. CEG utilizes various programs for developing and retaining employees that focus on employee engagement and belonging, as well as continuing education. Employee performance is measured in part based on goals that are aligned with the Company’s annual objectives.

CEG is committed to maintaining a workplace that acknowledges, encourages and values its employees as individuals. The Company and CEG believe that individual differences, experiences, and strengths enrich a company’s culture and help it better understand the needs of its customers and the communities in which it operates.

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 investors around ESG issues and to comply with ESG disclosure requirements. The Company’s Board of Directors reviews developing trends and emerging ESG matters as well as the Company’s strategies, activities, policies and communications regarding ESG matters, and reviews and considers potential actions the Company could take regarding ESG matters.

13

Aligned with the Company’s strategy of owning and acquiring environmentally-sound assets, in 2025, approximately 91% of the Company’s total operating revenues were not tied to the dispatch of power generation emitting GHGs. This non-GHG emitting operating revenue included renewable energy generation and grid reliability services in the Company’s Renewables & Storage segment and grid reliability services in the Flexible Generation segment at the El Segundo, Marsh Landing and Walnut Creek facilities. Excluding the Carlsbad facility, which is currently under a long-term tolling agreement whereby the Company does not control the dispatch of the facility, in 2025, approximately 97% of the Company’s total operating revenues were not tied to the dispatch of power generation emitting GHGs.

Also in 2025, 98% of the Company’s total generation was attributable to renewable energy and storage assets. The Company has also issued $2,725 million 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 facilities and assets meeting certain criteria focused on the supply of energy from renewable resources, including solar energy and wind energy, which includes the 2034 Senior Notes that were issued on January 13, 2026, as further described in Item 15 — Note 10, Long-term Debt.

Available Information

The Company’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’s website, www.sec.gov, and through the “Investor Relations” section of the Company’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 its website. The information posted on the Company’s website is not a part of this report.