wdq-20260630

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)


☒			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2026


☐			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: 001-40272

OPAL FUELS INC.

(Exact name of registrant as specified in its charter)


Delaware						80-0990453
(State or other jurisdiction of incorporation or organization)						(I.R.S. Employer Identification No.)

One North Lexington Avenue, Suite 1450
White Plains, New York						10601
(Address of principal executive offices)						(Zip Code)

(914) 705-4000

(Registrant's telephone number, including area code)

Not Applicable

(Former name, former address and former fiscal year, if changed since last report)

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Class A Common Stock, par value $0.0001 per share	OPAL	The Nasdaq Stock Market LLC

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 ☒ No ☐

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 ☒ No ☐

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 accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth 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. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

As of August 6, 2026, a total of 30,357,544 shares of Class A common stock, par value $0.0001 per share, 121,500,000 shares of Class B common stock, par value of $0.0001 per share and 22,899,037 shares of Class D common stock, par value $0.0001 per share were outstanding.

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995, that involve risks and uncertainties. All statements other than statements of historical facts contained in this Quarterly Report on Form 10-Q, including statements regarding our future results of operations or financial condition, business strategy and plans and objectives of management for future operations, are forward-looking statements. Words such as “anticipates,” “believes,” “could,” “estimates,” “expects,” “forecasts,” “future,” “goal,” “intends,” “may,” “objective,” “outlook,” “plans,” "potential," “projected,” “propose,” “seeks,” “should,” “target,” “will,” “would” and variations of these words or similar expressions (or the negative versions of such words or expressions) are intended to identify forward-looking statements. These forward-looking statements are not guarantees of future performance, conditions or results, and involve a number of known and unknown risks, uncertainties, assumptions and other important factors, many of which are outside our control, which could cause actual results or outcomes to differ materially from those discussed in the forward-looking statements. Important factors, among others, which may affect actual results or outcomes include:

▪our ability to grow and manage growth profitably, and maintain relationships with customers and suppliers;

▪our success in retaining or recruiting, our principal officers, key employees or directors;

▪intense competition and competitive pressures from other companies in the industry in which we operate;

▪increased costs of, or delays in obtaining, key components or labor for the construction and completion of LFG (as defined below) and livestock waste projects that generate electricity and RNG (as defined below), CNG (as defined below) and hydrogen dispensing stations;

▪factors relating to our business, operations and financial performance, including market conditions and global and economic factors beyond our control;

▪the reduction or elimination of government economic incentives to the renewable energy market;

▪factors associated with companies that are engaged in the production and integration of RNG, including (i) anticipated trends, growth rates and challenges in those businesses and in the markets in which they operate, (ii) contractual arrangements with, and the cooperation of, owners and operators of the landfill and livestock biogas conversion project facilities, on which we operate our LFG and livestock waste projects that generate electricity and (iii) RNG prices for Environmental Attributes (as defined below), LCFS (as defined below) credits and other incentives;

▪the ability to identify, acquire, develop and operate renewable projects and Fueling Stations (as defined below);

▪our ability to issue equity or equity-linked securities or obtain or amend debt financing;

▪the demand for renewable energy not being sustained;

▪impacts of climate change, changing weather patterns and conditions and natural disasters; and

▪the effect of legal, tax and regulatory changes.

The forward-looking statements contained in this Quarterly Report on Form 10-Q are based on current expectations and beliefs concerning future developments and their potential effects on us. There can be no assurance that future developments affecting us will be those that we have anticipated. These forward-looking statements involve a number of risks, uncertainties (some of which are beyond our control) or other assumptions that may cause actual results or performance to be materially different from those expressed or implied by these forward-looking statements. These risks and uncertainties include, but are not limited to, those factors described under the heading “Risk Factors” in this Quarterly Report on Form 10-Q and in our Annual Report on Form 10-K, which was filed with the SEC on March 16, 2026 (our “Annual Report”). Should one or more of these risks or uncertainties materialize, or should any of our assumptions prove incorrect, actual results may vary in material respects from those projected in these forward-looking statements. We undertake no obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as may be required under applicable securities laws.

TABLE OF CONTENTS


		PAGE
PART I. FINANCIAL INFORMATION
ITEM 1.	FINANCIAL STATEMENTS (Unaudited)	1
	Condensed Consolidated Balance Sheets as of June 30, 2026 and December 31, 2025	1
	Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2026 and 2025	3
	Condensed Consolidated Statements of Comprehensive (Loss) Income for the three and six months ended June 30, 2026 and 2025	4
	Condensed Consolidated Statements of Changes In Redeemable Non-Controlling Interest, Redeemable Preferred Non-Controlling Interest And Stockholders ' Equity (Deficit) for the three and six months ended June 30, 2026 and 2025	5
	Condensed Consolidated Statements of Cash Flows for the six months ended June 30 , 2026 and 2025	7
	Notes To Condensed Consolidated Financial Statements	9
ITEM 2.	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	30
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	45
ITEM 4.	CONTROLS AND PROCEDURES	45
PART II. OTHER INFORMATION
ITEM 1.	LEGAL PROCEEDINGS	46
ITEM 1A.	RISK FACTORS	46
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	46
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	46
ITEM 4.	MINE SAFETY DISCLOSURES	46
ITEM 5.	OTHER INFORMATION	46
ITEM 6.	EXHIBITS	47
SIGNATURES		48

Glossary of Key Terms

This Quarterly Report on Form 10-Q uses several terms of art that are specific to our industry and business. For the convenience of the reader, a glossary of such terms is provided here. Capitalized terms that are used in this Quarterly Report on Form 10-Q are either defined when they are first used or in the Glossary. Unless we otherwise indicate, or unless the context requires otherwise, any references in this Quarterly Report on Form 10-Q to:

“ArcLight” refers to ArcLight Clean Transition Corp. II, a blank check company incorporated as a Cayman Islands exempt company, and our previous name prior to the closing of the Business Combination.

“Business Combination” refers to the transactions contemplated by the Business Combination Agreement dated as of December 2, 2021 (as the same has been or may be amended, modified, supplemented or waived from time to time), by and among ArcLight, OPAL Fuels and OPAL Holdco LLC.

“Central Valley” refers to the consolidated variable interest entity of Central Valley RNG Holdings LLC and its subsidiaries.

“Class A common stock” refers to the shares of Class A common stock, par value $0.0001 per share, of OPAL.

“Class B common stock” refers to the shares of Class B common stock, par value $0.0001 per share, of OPAL.

“Class C common stock” refers to the shares of Class C common stock, par value $0.0001 per share, of OPAL.

“Class D common stock” refers to the shares of Class D common stock, par value $0.0001 per share, of OPAL.

“CMS” refers to CMS RNG LLC, a consolidated variable interest entity formed on May 9, 2025 as a joint venture to develop, construct, own, and operate a renewable natural gas facility. The Company holds a 70% membership interest in CMS, with the remaining 30% owned by a third‑party partner.

“Company”, “we”, “our”, “us” or similar terms refers to OPAL Fuels Inc. individually or on a consolidated basis, as the context may require.

“Exchange Act” refers to the Securities Exchange Act of 1934, as amended.

“FASB” refers to the Financial Accounting Standards Board.

“Fortistar” refers to Fortistar LLC, a Delaware limited liability company.

“Fueling Stations” refers to facilities where (i) natural gas is dispensed into fuel tanks of vehicles for use as transportation fuel, and (ii) transactional data from the dispensing of the fuel is recorded so that Environmental Attributes can be subsequently reported, matched with the dispensed fuel to the extent sourced from RNG, and generated under the federal or state RFS or LCFS programs and other current and potential future programs aimed at providing support for RNG into the transportation market. At the Fueling Stations, the natural gas is pressurized using compressor systems and, in this state, is referred to as CNG. Because Environmental Attributes associated with RNG are nominated/assigned to the physical quantity of CNG dispensed at the Fueling Station, when the CNG is dispensed into fuel tanks for use as transportation fuel and subsequently reported to the EPA and/or state environmental agency and matched with the production of RNG, the respective RINs and LCFS credits are generated. Some of these stations are designed, developed, constructed, operated and maintained by us while others are third party stations where we may only provide maintenance services.

“Hillman” refers to Hillman RNG Investments, LLC, a Delaware limited liability company and an affiliate of Fortistar.

“OPAL Intermediate Holdco” refers to OPAL Fuels Intermediate Holding Company LLC an indirect wholly owned subsidiary of the Company.

“OPAL Term Loan” refers to the term loan agreement entered into on October 22, 2021, by OPAL Intermediate Holdco with a syndicate of lenders.

“Paragon Loan” refers to the senior secured delayed‑draw term loan and related revolving loan facilities governed by the Amended and Restated Credit Agreement, under which Paragon RNG LLC, the Company’s joint venture, is the borrower and certain of its subsidiaries are guarantors.

"Preferred Coupon" refers to the 12% per annum preferred quarterly distribution rate applicable to the Series A preferred units, compounding quarterly.

"Preferred Units" refers, collectively, to the Series A-1 preferred units held by Hillman, the Series A preferred units previously held by a NextEra affiliated entity, and the new Series A preferred units held by Preferred Fuels.

“Sarbanes-Oxley Act” refers to the Sarbanes-Oxley Act of 2002.

“Securities Act” refers to the Securities Act of 1933, as amended.

“Sunoma” refers to Sunoma Holdings LLC and its wholly‑owned subsidiary, Sunoma Renewable Biofuel LLC, which together are owned 90% by OPAL Fuels Inc. and 10% by Paloma Dairy LLC.

“Sunoma Loan” refers to the debt agreement entered into on August 27, 2020 by Sunoma Renewable Biofuel LLC, an indirect wholly‑owned subsidiary of the Company, with Live Oak Banking Company.

“45Z” refers to Production Tax Credits.

In addition, the following is a glossary of key industry terms used herein:

“AAA” refers to the American Arbitration Association.

“ATM” refers to At Market Issuance Sales Agreement.

“Btu” refers to British thermal units.

“CI” refers to carbon intensity.

“CNG” refers to compressed natural gas.

“D3” refers to cellulosic biofuel with a 60% GHG reduction requirement.

“Environmental Attributes” refer to federal, state and local government incentives in the United States, provided in the form of RINs, RECs, LCFS credits, rebates, tax credits and other incentives to end users, distributors, system integrators and manufacturers of renewable energy projects, that promote the use of renewable energy.

“EPA” refers to the U.S. Environmental Protection Agency.

"GGE" or "GGEs" refers to gasoline gallon equivalent(s), a unit of measurement used to compare the energy content of alternative fuels to that of gasoline.

“GHG” refers to greenhouse gases.

“ITC” refers to Investment Tax Credit.

“LCFS” refers to Low Carbon Fuel Standard or similar types of federal and state programs.

“LFG” refers to landfill gas.

“RECs” refers to renewable energy credits.

“Renewable Power” refers to electricity generated from renewable sources.

“RFS” refers to the EPA’s Renewable Fuel Standard.

“RINs” refers to Renewable Identification Numbers.

“RNG” refers to renewable natural gas.

“RVOs” refers to renewable volume obligations

“VIEs” refers to variable interest entities.

Part I - Financial Information

Item 1. Financial Statements

OPAL FUELS INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands of U.S. dollars, except share and per share data)


	June 30, 2026		December 31, 2025
Assets(1)	(Unaudited)
Current assets:
Cash and cash equivalents	$	91,363	$	24,408
Accounts receivable, net of allowances of $1,040 and $469, respectively(2)	37,517		61,806
Restricted cash - current	915		1,210
Contract assets	6,638		8,276
Parts inventory	12,581		10,964
Prepaid expense and other current assets	14,335		16,018
Total current assets	163,349		122,682
Property, plant, and equipment, net	525,773		495,634
Investments in other entities	234,298		231,223
Net investment in sales-type lease	10,604		8,224
Restricted cash - non-current	2,914		2,700
Goodwill	54,608		54,608
Other long-term assets	48,698		44,398
Total assets	1,040,244		959,469
Liabilities and Stockholders' Equity (Deficit)(1)
Current liabilities:
Accounts payable(3)	13,107		19,004
Contract liabilities	3,052		6,296
Loan, current portion	18,882		15,062
Accrued expenses and other current liabilities	54,843		63,857
Total current liabilities	89,884		104,219
Loans, net of debt issuance costs	412,809		337,063
Other long-term liabilities	21,199		20,430
Total liabilities	523,892		461,712
Commitments and contingencies Note 12
Redeemable preferred non-controlling interests	158,400		130,000
Redeemable non-controlling interests	320,053		377,898
Stockholders' equity (deficit)
Class A common stock, $0.0001 par value, shares issued: 31,993,327 and 30,633,161 as of June 30, 2026 and December 31, 2025, respectively; shares outstanding: 30,357,544 and 28,997,378 as of June 30, 2026 and December 31, 2025, respectively	3		3
Class B common stock, $0.0001 par value, 121,500,000 issued and outstanding as of June 30, 2026 and December 31, 2025	12		12
Class C common stock, $0.0001 par value; none issued and outstanding as of June 30, 2026 and December 31, 2025	—		—
Class D common stock, $0.0001 par value, 22,899,037 shares issued and outstanding as of June 30, 2026 and December 31, 2025	2		2
Retained earnings (accumulated deficit)	37,535		(1,307)
Accumulated other comprehensive income (loss)	416		(26)
Class A common stock in treasury, at cost; 1,635,783 as of June 30, 2026 and December 31, 2025	(11,614)		(11,614)
Total stockholders' equity (deficit) attributable to the Company	26,354		(12,930)
Non-redeemable non-controlling interests	11,545		2,789
Total stockholders' equity (deficit)	37,899		(10,141)
Total liabilities, redeemable preferred, redeemable non-controlling interests and stockholders' equity (deficit)	$	1,040,244	$	959,469

(1) Includes amounts related to consolidated VIEs, which are presented separately in the table below.

(2) Includes related‑party amounts of $1,016 and $13,318 as of June 30, 2026 and December 31, 2025, respectively.

(3) Includes related‑party amounts of $2,715 and $8,951 as of June 30, 2026 and December 31, 2025, respectively.

The following table presents the aggregated assets and liabilities of consolidated VIEs, which are included in the consolidated balance sheets above.


	June 30, 2026		December 31, 2025
	(Unaudited)
Assets of consolidated VIEs, included in total assets above:
Cash and cash equivalents	$	1,208	$	87
Accounts receivable	9		38
Restricted cash - current	915		1,210
Prepaid expense and other current assets	105		131
Property, plant, and equipment, net	64,407		42,643
Restricted cash - non-current	2,914		2,700
Total assets of consolidated VIEs	69,558		46,809
Liabilities of consolidated VIEs, included in total liabilities above:
Accounts payable	53		390
Accounts payable, related party	236		227
Loan, current portion	2,271		2,457
Accrued expenses and other current liabilities	10,290		12,431
Loan, net of debt issuance costs	15,756		16,618
Other long-term liabilities	—		582
Total liabilities of consolidated VIEs	$	28,606	$	32,705

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

OPAL FUELS INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands of U.S. dollars, except share and per share data)

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Revenues:
RNG fuel(1)	$	23,821	$	25,130	$	45,459	$	52,729
Fuel station services(2)	53,064		47,026		97,630		97,704
Renewable power(3)	6,514		8,300		13,685		15,430
Total revenues	83,399		80,456		156,774		165,863
Operating expenses:
Cost of sales - RNG fuel	12,282		11,414		25,111		23,567
Cost of sales - Fuel station services	40,362		38,731		75,752		78,453
Cost of sales - Renewable power	6,285		6,899		11,915		13,661
Project development and startup costs	3,301		3,477		5,116		9,558
Selling, general and administrative	14,274		17,460		29,458		33,427
Depreciation, amortization, and accretion	5,167		5,264		10,780		11,206
Impairment loss	4,142		—		4,142		—
Loss (income) from equity method investments	597		(1,962)		2,354		(1,240)
Total operating expenses	86,410		81,283		164,628		168,632
Operating loss	(3,011)		(827)		(7,854)		(2,769)
Other expense
Interest and financing expense	(8,647)		(6,637)		(15,291)		(13,087)
Interest income	2,101		270		2,861		655
Other income, net	672		1,067		97		2,321
Total other expenses	(5,874)		(5,300)		(12,333)		(10,111)
Net loss before income tax benefit	(8,885)		(6,127)		(20,187)		(12,880)
Income tax benefit	4,738		13,686		10,447		21,723
Net (loss) income	(4,147)		7,559		(9,740)		8,843
Net (loss) income attributable to redeemable non-controlling interest	(7,136)		3,982		(19,703)		2,808
Net income attributable to non-redeemable non-controlling interest	137		160		219		236
Accretion of the redeemable preferred non-controlling interest to its redemption amount	4,353		2,617		13,887		5,234
Net (loss) income attributable to Class A common stockholders	$	(1,501)	$	800	$	(4,143)	$	565
Weighted average shares outstanding of Class A common stock:
Basic	29,641,216		28,265,710		28,966,490		27,995,258
Diluted	29,641,216		29,229,245		28,966,490		28,688,505
Per share amounts:
Basic	$	(0.05)	$	0.03	$	(0.14)	$	0.02
Diluted	$	(0.05)	$	0.03	$	(0.14)	$	0.02

(1) Includes revenues from related parties of $125 and $17,878 for the three months ended June 30, 2026 and 2025, respectively.

Includes revenues from related parties of $17,167 and $37,979 for the six months ended June 30, 2026 and 2025, respectively.

(2) Includes revenues from related parties of $3,251 and $12,826 for the three months ended June 30, 2026 and 2025, respectively.

Includes revenues from related parties of $16,358 and $29,429 for the six months ended June 30, 2026 and 2025, respectively.

(3) Includes revenues from related parties of $0 and $1,488 for the three months ended June 30, 2026 and 2025, respectively.

Includes revenues from related parties of $872 and $2,654 for the six months ended June 30, 2026 and 2025, respectively.

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

OPAL FUELS INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME

(In thousands of U.S. dollars)

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Net (loss) income	$	(4,147)	$	7,559	$	(9,740)	$	8,843
Other comprehensive gain (loss)
Net unrealized gain (loss) on cash flow hedges	1,327		(336)		2,542		(901)
Total comprehensive (loss) income	(2,820)		7,223		(7,198)		7,942
Comprehensive (loss) income attributable to redeemable non-controlling interests	(6,040)		3,702		(17,603)		2,058
Comprehensive income attributable to non-redeemable non-controlling interests	137		160		219		236
Accretion of the redeemable preferred non-controlling interest to its redemption amount	4,353		2,617		13,887		5,234
Comprehensive (loss) income attributable to Class A common stockholders	$	(1,270)	$	744	$	(3,701)	$	414

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

OPAL FUELS INC.

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN REDEEMABLE NON-CONTROLLING INTEREST, REDEEMABLE PREFERRED NON-CONTROLLING INTEREST AND STOCKHOLDERS' EQUITY (DEFICIT)

(In thousands of U.S. dollars, except per share data)

(Unaudited)


	Class A Common Stock			Class B Common Stock			Class D Common Stock											Class A Common stock in treasury					Mezzanine Equity
	Shares	Amount		Shares	Amount		Shares	Amount		Additional Paid-in capital		Retained earnings (accumulated deficit)		Accumulated other comprehensive income (loss)		Non-redeemable non-controlling interests		Shares	Amount		Total Equity (Deficit)		Redeemable preferred non-controlling interests		Redeemable non-controlling interests
December 31, 2025	30,633,161	$	3	121,500,000	$	12	22,899,037	$	2	$	—	$	(1,307)	$	(26)	$	2,789	(1,635,783)	$	(11,614)	$	(10,141)	$	130,000	$	377,898
Net loss	—	—		—	—		—	—		—		(986)		—		82		—	—		(904)		—		(4,689)
Other comprehensive income	—	—		—	—		—	—		—		—		210		—		—	—		210		—		1,005

Issuance of Class A common stock for vesting of equity awards net of tax withholdings	1,360,166	—		—	—		—	—		(1,343)		—		—		—		—	—		(1,343)		—		—
Stock-based compensation	—	—		—	—		—	—		357		—		—		—		—	—		357		—		1,698
Distributions to non-redeemable non-controlling interests	—	—		—	—		—	—		—		—		—		(65)		—	—		(65)		—		—

Change in redemption value of redeemable non-controlling interests	—	—		—	—		—	—		986		23,581		—		—		—	—		24,567		—		(24,567)
Payment of preferred dividend	—	—		—	—		—	—		—		—		—		—		—	—		—		(3,444)		—
Capital contribution from non-redeemable non-controlling interests	—	—		—	—		—	—		—		—		—		7,402		—	—		7,402		—		—
Redeemable preferred non-controlling interest issuance, net of issuance costs and warrants	—	—		—	—		—	—		—		—		—		—		—	—		—		113,910		—
Redemption of redeemable preferred non‑controlling interest	—	—		—	—		—	—		—		—		—		—		—	—		—		(100,000)		—
Accretion of the redeemable preferred non-controlling interest to its redemption amount	—	—		—	—		—	—		—		(1,656)		—		—		—	—		(1,656)		9,534		(7,878)
March 31, 2026	31,993,327	3		121,500,000	12		22,899,037	2		—		19,632		184		10,208		(1,635,783)	(11,614)		18,427		150,000		343,467
Net loss	—	—		—	—		—	—		—		(745)		—		137		—	—		(608)		—		(3,539)
Other comprehensive income	—	—		—	—		—	—		—		—		232		—		—	—		232		—		1,095

Issuance of Class A common stock for vesting of equity awards net of tax withholdings	—	—		—	—		—	—		(29)		—		—		—		—	—		(29)		—		—
Stock-based compensation	—	—		—	—		—	—		358		—		—		—		—	—		358		—		1,702


Change in redemption value of redeemable non-controlling interests	—	—		—	—		—	—		(329)		19,404		—		—		—	—		19,075		—		(19,075)
Payment of preferred dividend	—	—		—	—		—	—		—		—		—		—		—	—		—		(3,841)		—
Capital contribution from non-redeemable non-controlling interests	—	—		—	—		—	—		—		—		—		1,200		—	—		1,200		—		—
Redeemable preferred non-controlling interest issuance, net of issuance costs and warrants	—	—		—	—		—	—		—		—		—		—		—	—		—		7,888		—

Accretion of the redeemable preferred non-controlling interest to its redemption amount	—	—		—	—		—	—		—		(756)		—		—		—	—		(756)		4,353		(3,597)
June 30, 2026	31,993,327	$	3	121,500,000	$	12	22,899,037	$	2	$	—	$	37,535	$	416	$	11,545	(1,635,783)	$	(11,614)	$	37,899	$	158,400	$	320,053


	Class A Common Stock			Class B Common Stock			Class D Common Stock											Class A Common stock in treasury					Mezzanine Equity
	Shares	Amount		Shares	Amount		Shares	Amount		Additional Paid-in capital		Retained earnings (accumulated deficit)		Accumulated other comprehensive income (loss)		Non-redeemable non-controlling interests		Shares	Amount		Total (Deficit) Equity		Redeemable preferred non-controlling interests		Redeemable non-controlling interests
December 31, 2024	30,065,260	$	3	71,500,000	$	7	72,899,037	$	7	$	—	$	(137,004)	$	152	$	618	(1,635,783)	$	(11,614)	$	(147,831)	$	130,000	$	482,863
Net income	—	—		—	—		—	—		—		202		—		76		—	—		278		—		1,006
Other comprehensive loss	—	—		—	—		—	—		—		—		(94)		—		—	—		(94)		—		(469)
Issuance of Class A common stock for vesting of equity awards net of tax withholdings	542,404	—		—	—		—	—		(382)		—		—		—		—	—		(382)		—		—
Stock-based compensation	—	—		—	—		—	—		293		—		—		—		—	—		293		—		1,458
Distributions to non-redeemable non-controlling interests	—	—		—	—		—	—		—		—		—		(60)		—	—		(60)		—		—
Accretion of the redeemable preferred non-controlling interest to its redemption amount	—	—		—	—		—	—				(437)		—		—		—	—		(437)		2,617		(2,180)
Change in redemption value of Redeemable non-controlling interests	—	—		—	—		—	—		89		205,870		—		—		—	—		205,959		—		(205,959)
Payment of preferred dividend	—	—		—	—		—	—		—		—		—		—		—	—		—		(2,617)		—
March 31, 2025	30,607,664	3		71,500,000	7		72,899,037	7		—		68,631		58		634		(1,635,783)	(11,614)		57,726		130,000		276,719
Net income	—	—		—	—		—	—		—		1,237		—		160					1,397		—		6,162
Other comprehensive loss	—	—		—	—		—	—		—		—		(56)		—		—	—		(56)		—		(282)
Issuance of Class A common stock under the ATM program	17,104	—		—	—		—	—		58		—		—		—		—	—		58		—		—
Share conversion	—	—		50,000,000	5		(50,000,000)	(5)		—		—		—		—		—	—		—		—		—
Issuance of Class A common stock for vesting of equity awards net of tax withholdings	7,192	—		—	—		—	—		(5)		—		—		—		—	—		(5)		—		—
Stock-based compensation	—	—		—	—		—	—		369		—		—		—		—	—		369		—		1,835
Distributions to non-redeemable non-controlling interests	—	—		—	—		—	—		—		—		—		(50)		—	—		(50)		—		—
Accretion of the redeemable preferred non-controlling interest to its redemption amount	—	—		—	—		—	—		—		(438)		—		—		—	—		(438)		2,617		(2,180)
Capital contribution from non-redeemable non-controlling interests	—	—		—	—		—	—		—		—		—		1,991		—	—		1,991		—		—
Change in redemption value of Redeemable non-controlling interests	—	—		—	—		—	—		(422)		(82,872)		—		—		—	—		(83,294)		—		83,294
Payment of preferred dividend	—	—		—	—		—	—		—		—		—		—		—	—		—		(2,617)		—
June 30, 2025	30,631,960	$	3	121,500,000	$	12	22,899,037	$	2	$	—	$	(13,442)	$	2	$	2,735	(1,635,783)	$	(11,614)	$	(22,302)	$	130,000	$	365,548

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

OPAL FUELS INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands of U.S. dollars)

(Unaudited)


	Six Months Ended June 30,
	2026		2025
Cash flows from operating activities:
Net (loss) income	$	(9,740)	$	8,843
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation, amortization, and accretion	10,780		11,206
Stock-based compensation	4,115		3,956
Allowance for accounts receivable	571		2,454
Assets' impairment	4,142		—

(Loss) income from investments in other entities	2,354		(1,240)
Distributions from return on investments in other entities	669		2,620
Deferred income taxes	(10,630)		—




Other	1,224		(949)
Changes in operating assets and liabilities:
Accounts receivable(1)	23,718		(10,500)
Parts inventory	(1,617)		(2,710)
Prepaid expenses and other current and long-term assets	10,812		10,682
Accounts payable(2)	(4,950)		3,526
Accrued expenses and other current and non-current liabilities	(7,771)		(6,083)
Net cash provided by operating activities	23,677		21,805
Cash flows from investing activities:
Purchase of property, plant, and equipment	(52,680)		(33,409)

Distributions from return of investments in other entities	7,006		9,100
Cash paid, related to investments in other entities	(13,482)		(11,717)

Proceeds from disposal of property, plant and equipment	700		—
Net cash used in investing activities	(58,456)		(36,026)
Cash flows from financing activities:
Proceeds from loans	128,382		40,000
Repayment of loans	(49,542)		(15,863)
Proceeds from redeemable preferred non-controlling interest and warrants issuance, net of issuance costs	124,558		—
Redemption of redeemable preferred non‑controlling interest	(100,000)		—
Financing costs paid to other third parties	(947)		(1,250)
Proceeds from issuance of shares of Class A common stock under the ATM program, net	—		58
Repayment of principal portion of finance lease liabilities	(678)		(707)
Payment of preferred dividends	(7,285)		(5,234)
Distribution to non-redeemable non-controlling interest	(65)		(110)
Cash paid for taxes related to net share settlement of equity awards	(1,372)		(387)
Capital contribution from non-redeemable non-controlling interests	8,602		1,991
Net cash provided by financing activities	101,653		18,498
Net increase in cash, restricted cash, and cash equivalents	66,874		4,277
Cash, restricted cash, and cash equivalents, beginning of period	28,318		29,228
Cash, restricted cash, and cash equivalents, end of period	$	95,192	$	33,505

(1) Includes decrease (increase) from related parties of $12,302 and $(10,974) for the six months ended June 30, 2026 and 2025, respectively

(2) Includes (decrease) increase from related parties of $(6,236) and $356 for the six months ended June 30, 2026 and 2025, respectively


Supplemental disclosure of cash flow information
Interest paid, net of $1,327 and $1,241 capitalized, respectively	$	14,690	$	13,304

Noncash investing and financing activities:

Issuance of warrants in connection with redeemable preferred non-controlling interest financing	$	2,760	$	—

Purchase of property, plant and equipment included in accrued expenses and other current liabilities	$	19,941	$	24,859

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

OPAL FUELS INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation and Principles of Consolidation

The unaudited condensed consolidated financial statements are prepared in accordance with generally accepted accounting principles in the United States ("U.S. GAAP"). The Company’s unaudited condensed consolidated financial statements include the assets and liabilities of these subsidiaries. All intercompany transactions and balances have been eliminated in consolidation. In the opinion of management, the Company's financial statements include all normal and recurring adjustments necessary in order to make the financial statements not misleading and to provide a fair presentation of the Company's financial results for the interim period included in this Quarterly Report. The information included in this Quarterly Report should be read in conjunction with the Company's audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2025.

The Company consolidates all entities in which it holds a majority voting interest, as well as variable interest entities ("VIEs") for which it is determined to be the primary beneficiary. The Company's variable interests in each of the VIEs arise primarily from ownership of membership interests, construction commitments, the provision of operating and maintenance services, and the provision of environmental credit processing services to VIEs. The Company reassesses its primary beneficiary status on an ongoing basis.

Noncontrolling interests related to the Company’s VIEs are presented separately from stockholders' equity (deficit) on the condensed consolidated balance sheets and are reported as non-redeemable non-controlling interests within the condensed consolidated statements of changes in redeemable non-controlling interest, redeemable preferred non-controlling interest and stockholders' equity (deficit).

Certain amounts in the prior‑period financial statements have been reclassified to conform to the current‑period presentation. These reclassifications had no impact on previously reported total assets, total liabilities, stockholders' deficit, net loss, or condensed consolidated statements of cash flows.

Use of Estimates

The preparation of condensed consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the condensed consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

The significant estimates and assumptions of the Company include the residual value of the useful lives of property, plant and equipment, the fair value of long-lived assets, asset retirement obligations, percentage completion for revenue recognition, incremental borrowing rate for calculating the right-of-use assets and lease liabilities, and the fair value of the reporting units of goodwill.

Accounting Pronouncements Not Yet Adopted

In November 2024, the FASB issued ASU 2024-03, Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses, which requires additional, disaggregated disclosure about certain income statement expense line items. The ASU is effective for annual periods beginning after December 15, 2026, and interim periods beginning after December 15, 2027. The amendments are to be applied prospectively with the option for retrospective application. The Company is currently evaluating the impact that this guidance will have on the disclosures within our condensed consolidated financial statements.

In December 2025, the FASB issued ASU 2025-10, Accounting for Government Grants Received by Business Entities (Topic 832). This ASU establishes a unified accounting model for business entities when recognizing, measuring, and presenting government grants. The ASU categorizes grants as either related to an asset or related to income. A grant related to income is recognized in earnings in a systematic and rational manner over the periods in which the entity recognizes the related expenses for which the grant is intended to compensate. Presentation of the grant on the income statement can be either as a component of other income or as a deduction from the related expenses. The standard is effective for annual periods beginning after December 15, 2028 and interim periods within those annual periods. However, the ASU permits

early adoption. The Company is considering early adoption of ASU 2025-10 in the third quarter of 2026 and retrospective application of its provisions. The Company is currently evaluating the impact of adoption on its financial statements, including the presentation of Section 45z production tax credits.

Parts Inventory

Parts inventory, also referred to as supplies inventory, consists of shop spare parts inventory and construction site parts inventory. Parts inventory is stated at historical cost, which is determined using the average cost method, and is recorded at the lower of cost or net realizable value. An annual review of inventory is performed to identify obsolete items.

Environmental Credits Held for Sale

For the three months ended June 30, 2026 and 2025, the Company recorded $1,992 and $4,693 as part of Cost of sales - Fuel Station Services in the condensed consolidated statements of operations to adjust environmental credits held for sale to lower of cost and net realizable value. For the six months ended June 30, 2026 and 2025, the Company recorded $4,202 and $10,540, respectively.

Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities consist primarily of accrued capital expenditures, accrued payroll and related benefits, accrued environmental credit rebates, and other miscellaneous accrued operating expenses. Accrued environmental credit rebates represent the Company's liabilities for dispensing services provided by third-party vendors.


	June 30, 2026		December 31, 2025
Accrued capital expenditures	$	19,941	$	24,629
Accrued payroll	6,369		7,719
Accrued environmental credit rebates	5,197		4,993
Accrued expenses	11,670		12,062
Other current liabilities	11,666		14,454
Total accrued expenses and other current liabilities	$	54,843	$	63,857

Contract Balances

Contract assets consist primarily of costs and estimated earnings in excess of billings and retainage receivables. Costs and estimated earnings in excess of billings represent unbilled amounts earned and reimbursable under construction contracts and arise when revenues have been recognized but amounts are conditional and have yet to be billed under the terms of the contract. Amounts become billable in accordance with contract terms, generally based on progress toward completion and the achievement of contractual milestones. Cost and estimated earnings in excess of billings amounted to $5,140 and $6,489 as of June 30, 2026 and December 31, 2025, respectively.

Contract liabilities consist of billings in excess of costs and estimated earnings and other deferred construction revenue. Billings in excess of costs and estimated earnings represent amounts billed to or collected from customers in advance of the satisfaction of the related performance obligations. These amounts are recognized as revenue as the Company satisfies its performance obligations over the remaining contract term.

During the six months ended June 30, 2026, the Company recognized revenue of $3,510 that was included in contract liabilities at December 31, 2025. During the six months ended June 30, 2025, the Company recognized revenue of $3,404 that was included in contract liabilities at December 31, 2024.

Impairment

During the three months ended June 30, 2026, the Company recognized impairment charges of $3,595 related to certain long-lived assets in its Renewable Power segment and $547 related to certain long-lived assets in its Fuel Station Services segment. The impairment within its Renewable Power segment resulted from the Company's decision to repurpose a renewable power facility for use as an RNG facility. As a result of the change in intended use, certain assets associated with the renewable power facility were no longer expected to be utilized and had no alternative future use.

Accordingly, the Company determined that the fair value of the affected assets was zero and recorded an impairment charge equal to their carrying value.

Remaining Performance Obligations

The Company's remaining performance obligations represent the unrecognized revenue value of its contract commitments. The Company's remaining performance obligations may significantly vary each reporting period based on the timing of major new contract commitments. As of June 30, 2026, the Company had a remaining performance obligation of $32,653 of which $12,068 is expected to be recognized within the next 12 months.

Significant Customers, Vendors and Concentration of Credit Risk

At June 30, 2026, two customers accounted for 42% of accounts receivable. At December 31, 2025, four customers accounted for 63% of accounts receivable.

During the three and six months ended June 30, 2026, and three months ended June 30, 2025 no individual vendor accounted for more than 10% of the Company's total volume of total purchases. During the six months ended June 30, 2025, there was one supplier that accounted for approximately 13% of the Company’s total purchases.

Refer to Note 7. Reportable Segments and Geographic Information for details on revenue concentration.

2. INVESTMENTS IN OTHER ENTITIES AND VARIABLE INTEREST ENTITIES

The Company’s VIEs consist of landfill or dairy manure RNG facilities that are either under construction or in operation. OPAL’s share of design capacity for these facilities ranges from approximately 43,750 MMBtu to 1,327,140 MMBtu per year. These entities are financed through the Opal Term Loan, the Sunoma Loan, or the Paragon Loan. The Paragon Loan was obtained directly by the joint venture and is not consolidated.

VIEs for which the Company is not the primary beneficiary are accounted for under the equity method. As of June 30, 2026, Sunoma, Central Valley and CMS were consolidated VIEs.

The condensed consolidated balance sheets summarize the major consolidated balance sheet items for consolidated VIEs as of June 30, 2026 and December 31, 2025. The information is presented on an aggregate basis based on similar risk and reward characteristics and the nature of our involvement with the VIEs. All VIEs are RNG facilities reported under the RNG Fuel Supply segment, and the Company’s interests are primarily equity-based.

The following table presents the Company's ownership interests and carrying values of Investment in Other Entities:


	Pine Bend			Noble Road			GREP			Land2Gas			Paragon			Other			Total
Percentage of ownership	50		%	50		%	20		%	50		%	50		%	50		%
Balance at December 31, 2025	$	19,864		$	20,755		$	594		$	36,554		$	153,456		$	—		$	231,223
Balance at June 30, 2026	$	18,028		$	19,523		$	259		$	40,833		$	149,597		$	6,058		$	234,298

As of June 30, 2026 and December 31, 2025, the carrying value of the Company’s equity method investments exceeded its proportionate share of the underlying net assets of its investees by $118,746 and $122,165, respectively. This basis difference primarily relates to the gain recognized upon the deconsolidation of certain RNG project entities, which increased the Company’s investment basis. The Company determined that this basis difference is attributable to construction in progress and will be amortized over the related assets’ estimated useful life of 20 years beginning when the assets are placed in service. The amortization of this basis difference, which reduces equity in earnings, was $1,719 and $1,719, reflected in income from equity method investments in the condensed consolidated statements of operations for the three months ended June 30, 2026 and 2025, respectively. The amortization of this basis difference was $3,419 and $3,419 for the six months ended June 30, 2026 and 2025, respectively.

The following table summarizes the (loss) income from equity method investments:


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Revenue	$	34,599	$	31,757	$	61,910	$	54,274
Gross profit	6,657		11,567		9,901		14,382
Net (loss) income (1)	$	(597)	$	1,962	$	(2,354)	$	1,240

(1) Represents the Company's portion of the net (loss) income from equity method investments including amortization of any basis differences.

A summary of financial information for our portion of the assets and liabilities in equity method investees in the aggregate is as follows:


	June 30, 2026		December 31, 2025
Current assets	$	19,803	$	27,566
Noncurrent assets	324,676		305,900
Total assets	344,479		333,466
Current liabilities	41,574		35,874
Noncurrent liabilities	77,230		81,288
Total liabilities	$	118,804	$	117,162

The Company’s maximum exposure to loss is limited to its equity investment in the unconsolidated entities.

3. LOANS

The following table summarizes the borrowings under the various loan facilities as of June 30, 2026 and December 31, 2025:


			June 30, 2026		December 31, 2025
	Effective interest rate		Amount		Amount
OPAL Term Loan	8.4	%	$	421,563	$	321,618
Revolving Loan			—		20,000
Sunoma Loan	8.8	%	18,158		19,090
Equipment Loan	8.0	%	385		559
Less: unamortized debt issuance costs			(8,415)		(9,142)
Less: current portion of long-term loans			(18,882)		(15,062)
Total long-term loan			$	412,809	$	337,063

As of June 30, 2026, principal maturities of debt are expected as follows, excluding any undrawn debt facilities:



Fiscal year:
Six months ending December 31, 2026	$	9,505
2027	18,503
2028	399,171
2029	2,395
2030	2,589
Thereafter	7,943
	$	440,106

OPAL Term Loan

During the six months ended June 30, 2026, the Company drew $128,382 under its term loan facility pursuant to its existing credit agreement. A portion of the proceeds from the borrowing was used to repay $20,000 outstanding under the revolving loan facility. As of June 30, 2026, the Company had utilized $30,747 of availability under the revolver loan to provide for the issuance of letters of credit to support the operations of OPAL Fuels Intermediate HoldCo LLC (the “Borrower”) and certain subsidiaries of the Borrower (the “Guarantors”).

Beginning in the first quarter of 2026, the Company commenced principal payments under its credit agreement and became subject to a quarterly cash sweep pursuant to which, within two business days after the required delivery of quarterly financial statements, a percentage of distributable cash is required to be applied to repay outstanding borrowings, with the applicable percentage determined based on the Company’s consolidated debt to cash flow ratio. If the required financial statements are not delivered within the specified timeframe, 100% of distributable cash is required to be applied to the cash sweep.

On May 30, 2026, OPAL Fuels Inc. exercised its right pursuant to that certain Credit and Guarantee Agreement dated as of September 1, 2023 among the Borrower, direct and indirect subsidiaries of the Borrower as guarantors, the lenders party thereto as lenders, and Bank of America, N.A., as administrative agent, to contribute approximately $7,965 to Borrower in order for Borrower to maintain compliance with certain financial covenants under its credit facility.

Sunoma Loan

The Company utilized $927 for the issuance of letters of credit to support the operations.

4. LEASES

Lessor contracts

Sales-Type Leases

During the six months ended June 30, 2026, the Company entered into a new sales-type lease. Upon commencement, the carrying value of the underlying assets was removed from the balance sheet and a net investment in lease was recognized, measured at the present value of future lease payments discounted at the rate implicit in the lease. During the first quarter of 2026, $2,246 was recognized within fuel station services revenues and $1,838 was recorded in cost of sales - fuel station services.

As of June 30, 2026, a maturity analysis of lease receivables reflecting undiscounted cash flows to be received on an annual basis are as follows:


Fiscal year:
Six months ending December 31, 2026	$	952
2027	1,949
2028	1,997
2029	2,047
2030	2,098
Thereafter	11,413
Total undiscounted cash flows	20,456
Less: Discount based on implicit rate	10,507
Plus: Unguaranteed residual asset	655
Net investment in sales-type lease	$	10,604

5. DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS

Interest Rate Swap Contracts

The Company expects to release $1,116 from the other comprehensive income in the next twelve months.

The location and amounts of interest rate swaps and their fair values in the condensed consolidated balance sheets are:


In	June 30, 2026		December 31, 2025		Location of Fair Value Recognized in Balance Sheet
Derivatives designated as cash flow hedges:
Short term portion of the interest rate swaps	$	1,116	$	128	Prepaid expense and other current assets
Long term portion of the interest rate swaps	1,130		—		Other long-term assets
Long term portion of the interest rate swaps	—		(301)		Other long-term liabilities
	$	2,246	$	(173)

Commodity Swap Contracts

The following table summarizes the effect of commodity swaps on the condensed consolidated statements of operations for the three and six months ended June 30, 2026 and 2025:


	Location of Gain (Loss) Recognized	Three Months Ended June 30,				Six Months Ended June 30,
		2026		2025		2026		2025
Derivatives not designated as hedging instruments:
Commodity swaps - realized	Revenues - Renewable Power	$	5	$	32	$	(138)	$	(60)
Commodity swaps - unrealized	Revenues - Renewable Power	—		1		92		(12)
Commodity swaps - realized	Revenues - RNG Fuel	1,193		804		256		871
Commodity swaps - unrealized	Revenues - RNG Fuel	(424)		1,935		34		607
Total realized and unrealized gain		$	774	$	2,772	$	244	$	1,406

The following table summarizes the derivative assets and liabilities related to commodity swaps as of June 30, 2026 and December 31, 2025:


	Fair Value
	June 30, 2026		December 31, 2025		Location of Fair value recognized in Balance Sheet
Derivatives not designated as hedging instruments:
Current portion of unrealized gain on commodity swaps	$	2,116	$	1,933	Prepaid expense and other current assets
Current portion of unrealized loss on commodity swaps	—		(92)		Accrued expenses and other current liabilities
Non - current portion of unrealized gain on commodity swaps	—		149		Other long-term assets

Total commodity swaps - unrealized gain	$	2,116	$	1,990

There were no amounts offset in the condensed consolidated balance sheets as of the period-end dates. In addition, there were no collateral balances with counterparties outstanding as of the period-end dates.

Warrants

During the first quarter of 2026, the Company issued the Warrants with an initial estimated fair value of $2,760. Changes in fair value of $(555) and $155 were recognized in other (expense) income, net, for the three and six months ended June 30, 2026, respectively, resulting in an estimated fair value of $2,915 as of June 30, 2026. The key inputs into the Black-Scholes option pricing model for the Warrants were as follows for the relevant periods:


	As of June 30, 2026			As of March 6, 2026
Risk-free interest rate	4.4		%	4.0		%
Expected term (years)	7.7			8.0
Expected volatility	58.9		%	57.7		%
Exercise price	$	2.7		$	2.7
Stock price	$	2.2		$	2.1

Recurring Fair Value Measurements

There were no transfers of assets between Level 1, Level 2, or Level 3 of the fair value hierarchy as of June 30, 2026 and December 31, 2025.

The Company's assets and liabilities that are measured at fair value on a recurring basis include the following as of June 30, 2026 and December 31, 2025, set forth by level, within the fair value hierarchy:


	Fair values as of June 30, 2026
	Level 1		Level 2		Level 3		Total
Assets:
Money market funds	$	74,542	$	—	$	—	$	74,542
Interest rate swap contracts	—		2,246		—		2,246
Commodity swap contracts	—		2,116		—		2,116
Liabilities:
Warrants	$	—	$	—	$	2,915	$	2,915


	Fair values as of December 31, 2025
	Level 1		Level 2		Level 3		Total
Assets:
Money market funds	$	22,969	$	—	$	—	$	22,969

Commodity swap contracts	$	—	$	2,082	$	—	$	2,082

6. RELATED PARTIES

Related parties are represented by Fortistar LLC ("Fortistar") and other affiliates, subsidiaries and entities under common control with Fortistar or NextEra Energy Marketing, LLC (“NextEra”).

The following table summarizes revenues recorded from related parties:


	Three Months Ended June 30, 2026						Six Months Ended June 30, 2026
	RNG fuel		Fuel Station Services		Renewable Power		RNG fuel		Fuel Station Services		Renewable Power
Environmental Attributes (1), (5)	$	—	$	—	$	—	$	16,917	$	10,856	$	—
Commodity swaps (2), (5)	—		—		—		—		—		872
Environmental processing (3)	—		3,251		—		—		5,502		—
Service agreements (4)	125		—		—		250		—		—
Total	$	125	$	3,251	$	—	$	17,167	$	16,358	$	872


	Three Months Ended June 30, 2025						Six Months Ended June 30, 2025
	RNG fuel		Fuel Station Services		Renewable Power		RNG fuel		Fuel Station Services		Renewable Power
Environmental Attributes (1)	$	17,732	$	10,476	$	—	$	37,833	$	25,455	$	—
Commodity swaps (2)	—		—		1,488		—		—		2,654
Environmental processing (3)	—		2,350		—		—		3,974		—
Service agreements (4)	146		—		—		146		—		—
Total	$	17,878	$	12,826	$	1,488	$	37,979	$	29,429	$	2,654

(1) Represents RIN and LCFS sales to NextEra. Includes revenues of $5,586 recognized under the Green Gas Contract, which were recorded within RNG fuel revenues for the three months ended June 30, 2025. Includes revenues of $5,674 and $10,603 recognized under the Green Gas Contract, which were recorded within RNG fuel revenues for the six months ended June 30, 2026 and 2025, respectively.

(2) Represents revenue earned under ISDA and REC sales agreements with NextEra.

(3) Represents environmental processing fees earned under agreements with equity method investments, related to the generation and marketing of RINs and LCFS.

(4) Represents management fees earned under an agreement with Fortistar.

(5) Due to the repayment and redemption of NextEra's redeemable noncontrolling interest in March 2026, revenues and balances related to transactions with NextEra are no longer included in the Company's related-party disclosures beginning in the second quarter of 2026. Year-to-date amounts reported in subsequent quarters of 2026 will continue to include activity recognized during the first quarter of 2026, when NextEra was still considered a related party.

The following table summarizes the various fees recorded under the service agreements with related parties which are included in selling, general and administrative within the Company's condensed consolidated statements of operations:


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Staffing and management services	$	404	$	478	$	992	$	1,110
Rent - fixed compensation	194		118		379		348
IT services	1,220		1,066		2,444		2,031
Total related party fees	$	1,818	$	1,662	$	3,815	$	3,489

The following table presents the various balances for related parties included in the Company's condensed consolidated balance sheets as of June 30, 2026 and December 31, 2025:


	Location in Balance Sheet	June 30, 2026		December 31, 2025
Assets:
Trade AR - NextEra (1)	Accounts receivable, net of allowance	$	—	$	12,626
Other	Accounts receivable, net of allowance	1,016		692
Total receivables - related party		1,016		13,318
Liabilities:
Payables to equity method investment entities	Accounts payable	2,715		8,450
Other (1)	Accounts payable	—		501
Total liabilities - related party		$	2,715	$	8,951

(1) Due to the repayment and redemption of NextEra's redeemable noncontrolling interest in March 2026, revenues and balances related to transactions with NextEra are no longer included in the Company's related-party disclosures beginning in the second quarter of 2026.

7. REPORTABLE SEGMENTS AND GEOGRAPHIC INFORMATION

The Company is organized into three operating segments.

During the fourth quarter of 2025, the Company changed the presentation of information reviewed by the Chief Operating Decision Makers (“CODM”) to allocate certain corporate general and administrative costs, including consulting, insurance, and payroll expenses, to the related reportable segments. Segment information has been retrospectively revised to reflect this change. All the assets and revenue-generating activities, aside from sales‑type lease in Canada, were domiciled in the United States for the three and six months ended June 30, 2026 and 2025. Transactions between reportable segments are accounted for using market‑based pricing. Intersegment revenues and expenses are eliminated in consolidation.

For the three months ended June 30, 2025, amounts reallocated from Corporate to RNG Fuel, Fuel Station Services, and Renewable Power were $2,834, $658, and $1,160, respectively. For the six months ended June 30, 2025, amounts reallocated from Corporate to RNG Fuel, Fuel Station Services, and Renewable Power were $5,126, $994, and $2,122, respectively.

The following table reflects the financial data used to calculate each reportable segment’s income (loss) and includes reconciliations to the Company's consolidated revenue and consolidated net loss for the three months ended June 30, 2026:


	RNG Fuel		Fuel Station Services		Renewable Power		Total Segments		Corporate		Total
Revenue from external customers	$	23,821	$	53,064	$	6,514	$	83,399	$	—	$	83,399
Intersegment revenues	142		9,576		—		9,718		—		9,718
	23,963		62,640		6,514		93,117		—		93,117
Reconciliation of Revenue
Elimination of intersegment revenues											(9,718)
Total revenues	23,821		53,064		6,514		83,399		—		83,399

Segment and Corporate Expenses
Less: (1)
Cost of sales	12,282		40,362		6,285		58,929		—		58,929
Loss from equity method investments	597		—		—		597		—		597
Interest and financing expense, net	7,596		(1,027)		(23)		6,546		—		6,546
Project development and startup costs	3,301		—		—		3,301		—		3,301
Impairment loss	—		547		3,595		4,142		—		4,142
Depreciation, amortization, and accretion	3,143		1,606		418		5,167		—		5,167
Other corporate expenses	—		—		—		—		7,828		7,828
Stock-based compensation	—		—		—		—		2,060		2,060
Other segment items (2)	2,324		217		1,173		3,714		—		3,714
Segment (loss) income	(5,422)		11,359		(4,934)		1,003		(9,888)		(8,885)

Reconciliation of profit or loss (segment income / (loss))
Income tax benefit											4,738
Net loss											$	(4,147)

The following table reflects the financial data used to calculate each reportable segment’s income (loss) and includes reconciliations to Opal’s consolidated revenue and consolidated net loss for the six months ended June 30, 2026:


	RNG Fuel		Fuel Station Services		Renewable Power		Total Segments		Corporate		Total
Revenue from external customers	$	45,459	$	97,630	$	13,685	$	156,774	$	—	$	156,774
Intersegment revenues	284		14,607		—		14,891		—		14,891
	45,743		112,237		13,685		171,665		—		171,665
Reconciliation of Revenue
Elimination of intersegment revenues											(14,891)
Total revenues	45,459		97,630		13,685		156,774		—		156,774

Segment and Corporate Expenses
Less: (1)
Cost of sales	25,111		75,752		11,915		112,778		—		112,778
Loss from equity method investments	2,354		—		—		2,354		—		2,354
Interest and financing expense, net	13,932		(1,460)		(42)		12,430		—		12,430
Project development and startup costs	5,116		—		—		5,116		—		5,116
Impairment loss	—		547		3,595		4,142		—		4,142
Depreciation, amortization, and accretion	6,236		3,164		1,380		10,780		—		10,780
Other corporate expenses	—		—		—		—		18,836		18,836
Stock-based compensation	—		—		—		—		4,115		4,115
Other segment items (2)	4,796		154		1,460		6,410		—		6,410
Segment (loss) income	(12,086)		19,473		(4,623)		2,764		(22,951)		(20,187)

Reconciliation of profit or loss (segment income / (loss))
Income tax benefit											10,447
Net loss											$	(9,740)

(1) The significant expense categories and amounts align with the segment-level information that is regularly provided to the CODM. Intersegment expenses are included within the amounts shown in the line Cost of sales and no intersegment profit was recognized.

(2) Other segment items for each reportable segment include:

•RNG - payroll, consulting, insurance and other expenses

•Fuel Station Services - gain on RNG dispensing and payroll

•Renewable Power - payroll, consulting, insurance and other expenses

The following table reflects certain other financial data for the reportable segments as of June 30, 2026:


	RNG Fuel		Fuel Station Services		Renewable Power		Total Segments		Corporate		Total
Other segment disclosures
Investment in other entities	$	234,298	$	—	$	—	$	234,298	$	—	$	234,298
Segment assets	$	719,905	$	191,151	$	22,108	$	933,164	$	107,080	$	1,040,244

For the six months ended June 30, 2026, the Company made the following cash payments for capital expenditures:


	RNG Fuel		Fuel Station Services		Renewable Power		Total Segments		Corporate		Total
Cash paid for purchases of property, plant and equipment	$	45,461	$	7,219	$	—	$	52,680	$	—	$	52,680


	RNG Fuel		Fuel Station Services		Renewable Power		Total Segments		Corporate		Total
Revenue from external customers	$	25,130	$	47,026	$	8,300	$	80,456	$	—	$	80,456
Intersegment revenues	138		4,892		—		5,030		—		5,030
	25,268		51,918		8,300		85,486		—		85,486
Reconciliation of Revenue
Elimination of intersegment revenues											(5,030)
Total revenues	25,130		47,026		8,300		80,456		—		80,456

Segment and Corporate Expenses
Less: (1)
Cost of sales	11,414		38,731		6,899		57,044		—		57,044
Income from equity method investments	(1,962)		—		—		(1,962)		—		(1,962)
Interest and financing expense, net	6,387		(7)		(13)		6,367		—		6,367
Project development and startup costs	3,477		—		—		3,477		—		3,477
Depreciation, amortization, and accretion	2,995		1,317		952		5,264		—		5,264
Other corporate expenses	—		—		—		—		9,647		9,647
Stock-based compensation	—		—		—		—		2,205		2,205
Other segment items (2)	3,692		(311)		1,160		4,541		—		4,541
Segment (loss) income	(873)		7,296		(698)		5,725		(11,852)		(6,127)

Reconciliation of profit or loss (segment income / (loss))
Income tax benefit											13,686
Net income											$	7,559


	RNG Fuel		Fuel Station Services		Renewable Power		Total Segments		Corporate		Total
Revenue from external customers	$	52,729	$	97,704	$	15,430	$	165,863	$	—	$	165,863
Intersegment revenues	276		9,285		—		9,561		—		9,561
	53,005		106,989		15,430		175,424		—		175,424
Reconciliation of Revenue
Elimination of intersegment revenues											(9,561)
Total revenues	52,729		97,704		15,430		165,863		—		165,863

Segment and Corporate Expenses
Less: (1)
Cost of sales	23,567		78,453		13,661		115,681		—		115,681
Income from equity method investments	(1,240)		—		—		(1,240)		—		(1,240)
Interest and financing expense, net	12,404		56		(28)		12,432		—		12,432
Project development and startup costs	9,558		—		—		9,558		—		9,558
Depreciation, amortization, and accretion	5,954		3,351		1,901		11,206		—		11,206
Other corporate expenses	—		—		—		—		20,317		20,317
Stock-based compensation	—		—		—		—		3,956		3,956
Other segment items (2)	4,939		(163)		2,057		6,833		—		6,833
Segment (loss) income	(2,453)		16,007		(2,161)		11,393		(24,273)		(12,880)

Reconciliation of profit or loss (segment income / (loss))
Income tax benefit											21,723
Net income											$	8,843

(1) The significant expense categories and amounts align with the segment-level information that is regularly provided to the CODM. Intersegment expenses are included within the amounts shown in line Cost of sales and no intersegment profit was recognized.

(2) Other segment items for each reportable segment include:

•RNG - payroll, consulting, insurance and other expenses

•Fuel Station Services - payroll expenses and gain on RNG dispensing

•Renewable Power - payroll, consulting, insurance and other expenses

The following table reflects certain other financial data for the reportable segments for as of December 31, 2025:


	RNG Fuel		Fuel Station Services		Renewable Power		Total Segments		Corporate		Total
Other segment disclosures
Investment in other entities	$	231,223	$	—	$	—	231,223		$	—	$	231,223
Segment assets	$	675,988	$	196,853	$	28,740	$	901,581	$	57,888	$	959,469

For the six months ended June 30, 2025, the Company made the following cash payments for capital expenditures:


	RNG Fuel		Fuel Station Services		Renewable Power		Total Segments		Corporate		Total
Cash paid for purchases of property, plant and equipment	$	20,108	$	12,874	$	427	$	33,409	$	—	$	33,409

The following table reflects revenues from external customers by type for the reportable segments:


	Three Months Ended June 30,				Six Months Ended June 30,
(in thousands)	2026		2025			2026		2025
RNG Fuel
Environmental attributes	$	20,424	$	19,941		$	38,654	$	45,771
Brown gas sales and other	3,397		5,189			6,805		6,958
Total RNG Fuel	23,821		25,130			45,459		52,729
Fuel Station Services
OPAL owned stations	5,102		5,916			11,053		10,822
Environmental attributes and RNG marketing (1)	30,994		22,774			52,183		51,300
Third party station service and maintenance	7,125		6,534			13,925		13,604
Construction	6,329		9,183			11,228		17,174
Lease revenues (2)	3,514		2,619			9,241		4,804
Total Fuel Station Services	53,064		47,026			97,630		97,704
Renewable Power
Electricity sales	4,915		4,324			10,707		9,580
Environmental attributes	1,158		2,767			1,871		3,588
Lease revenues (3)	190		391			422		647
Other (4)	251		818			685		1,615
Total Renewable Power	6,514		8,300			13,685		15,430

Total revenues	$	83,399	$	80,456		$	156,774	$	165,863

Revenue from contracts with customers	$	79,695	$	77,446		$	147,111	$	160,412
Revenue from lease arrangements	$	3,704	$	3,010		$	9,663	$	5,451

(1) Revenues from RNG marketing in the Fuel Station Services segment relate to revenues earned from Environmental Attribute generation and monetization services.

(2) Fuel Station Services lease revenue relates to revenue from fuel purchasing agreements where we determined that we transferred the right to control the use of the station to the purchaser. Includes sales-type lease revenues of $—, $—, $2,246, and $— for the three months ended June 30, 2026 and 2025, and the six months ended June 30, 2026 and 2025, respectively, from customers domiciled outside of the United States. All remaining lease revenue relates to operating leases.

(3) Renewable Power operating lease revenue relates to revenue from power purchase agreements where we determined that we transferred the right to control the use of the power plant to the purchaser.

(4) Includes management fee revenues earned from management of operations of equity method entities.

The tables below outline the revenue from customers that comprise 10% or more of the Company's consolidated revenue, along with their respective percentages of revenue by each segment.


	Six Months Ended June 30,
	2026				2025
Customer A	Revenue		Percentage of total revenue		Revenue		Percentage of total revenue
RNG Fuel	$	35,455	23	%	$	37,833	23	%
Fuel Station Services	29,396		19	%	25,455		15	%
Renewable Power	1,690		1	%	2,654		1	%
Total	$	66,541	43	%	$	65,942	39	%

The tables below outline the revenue from customers that comprise 10% or more of our consolidated revenue, along with their respective percentages of revenue by each segment.


	Three Months Ended June 30,
	2026				2025
Customer A	Revenue		Percentage of total revenue		Revenue		Percentage of total revenue
RNG Fuel	18,538		22	%	$	17,732	22	%
Fuel Station Services	18,540		22	%	10,476		13	%
Renewable Power	818		1	%	1,488		2	%
Total	$	37,896	45	%	$	29,696	37	%

8. REDEEMABLE NON-CONTROLLING INTEREST, REDEEMABLE PREFERRED NON-CONTROLLING INTEREST AND STOCKHOLDERS' EQUITY

Common stock

As of June 30, 2026, the Company is authorized to issue 340,000,000 shares of Class A common stock, 160,000,000 shares of Class B common stock, 160,000,000 shares of Class C common stock, and 160,000,000 shares of Class D common stock.

Shares of Class B and Class D common stock do not have any economic value except voting rights as described below.

Redeemable Preferred Non-controlling Interests

Upon completion of the Business Combination, the Company effectively assumed the Series A‑1 and Series A preferred units previously issued by OPAL Fuels LLC to Hillman and NextEra, respectively. Following the transaction, these preferred units were presented as redeemable preferred non-controlling interests in the Company’s condensed consolidated financial statements.

On March 6, 2026, OPAL Fuels LLC (“Opal Fuels”), the Company’s primary operating consolidated subsidiary, entered into a subscription agreement (“Subscription Agreement”) with Preferred Fuels LLC, (“Preferred Fuels” or “Investor”), an entity under common control with the Company. Pursuant to the Subscription Agreement Preferred Fuels committed to purchase up to $180,000 (the “Offering”) of Series A preferred units of Opal Fuels in multiple closings. At the initial closing on March 6, 2026, Preferred Fuels purchased 1,200,000 preferred units for aggregate proceeds of $120,000. OPAL Fuels may, in its sole discretion, require Preferred Fuels to fund up to an additional $60,000 (or “Undrawn Commitment”) within one year of the initial closing (or “Availability Period”), subject to the terms of the Subscription Agreement. During the three months ended June 30, 2026 the Company drew $8,400 of additional funding from the Undrawn Commitment. Additionally, pursuant to the Subscription Agreement, the Investor also has a right of first offer to purchase up to an additional 700,000 Units for an aggregate purchase price of up to $70,000 in the Offering in the event that OPAL Fuels intends to sell any additional units prior to the two (2) year anniversary of the initial closing. Opal Fuels used the proceeds received from the issuance of the Series A preferred units on March 6, 2026 to redeem all of the previously issued and outstanding Series A preferred units.

In connection with the initial closing on March 6, 2026, OPAL Fuels Inc. issued to Preferred Fuels warrants (“Warrants”) to purchase up to 2,160,000 shares of Class A common stock (the “Warrant Shares”) at an exercise price per share of $2.67, subject to customary anti-dilution adjustments. The Warrants expire on March 6, 2034. A holder of the Warrants shall not have the right to exercise the Warrants without prior approval by the Company’s Board of Directors to the extent that after giving effect to such exercise, such person would beneficially own in excess of 19.9% of the Company’s outstanding common stock immediately after giving effect to such exercise. Up to 720,000 shares of the Warrant Shares are forfeitable if Preferred Fuels fails to fund issuance of the remaining Series A preferred units during the Availability Period provided Opal Fuels requested such funding.

Additionally, up to 840,000 shares issuable on a pro rata basis upon future purchases by Preferred Fuels of up to an additional 700,000 Series A preferred units (up to $70,000) within two years of the initial closing pursuant to its right of first offer. No Subsequent Warrant Shares have been issued as of June 30, 2026.

The Company recorded Series A preferred units as redeemable noncontrolling interest in its condensed consolidated financial statements at the amount of proceeds received, less the fair value of the Warrants of $2,760 and directly attributable issuance costs of $3,842. The Series A preferred units are subsequently remeasured to their redemption value as of each reporting date as if such reporting date were the redemption date. The Company concluded that the Warrants are not indexed to the Company’s equity. The Warrants are accounted for as liabilities in the Company’s condensed consolidated financial statements, within other long-term liabilities with changes in fair value recognized in other income, net.

As previously disclosed in a Current Report filed with the SEC on May 20, 2026, on May 18, 2026, OPAL Fuels amended and restated the terms of its Series A-1 Preferred Units to generally conform them to the terms of its Series A Preferred Units. The amendment increased the annual dividend rate from 8% to 12%, with only up to 2% payable in kind and the remainder payable in cash, revised certain redemption rights to permit holder redemption upon specified events including a change of control, certain uncured trigger events, or beginning on the fifth anniversary of March 6, 2026, and added enhanced holder protective provisions and remedies upon the occurrence of certain trigger events. The amendment also eliminated the holders' prior conversion rights upon delayed redemption of the preferred units. The Amended and Restated Certificate of Designations of Series A-1 Preferred Units does not, however, provide holders of Series A-1 Preferred Units with any rights to appoint members to the board of directors of the Company, which rights are provided to holders of Series A Preferred Units under the Amended and Restated Certificate of Designations of Series A Preferred Units.

The following table summarizes the changes in the redeemable preferred non-controlling interests which represent Series A and Series A-1 preferred units outstanding at OPAL Fuels level from December 31, 2025 to June 30, 2026:


	Series A-1 preferred units			Series A preferred units
	Units	Amount		Units	Amount		Total
Balance, December 31, 2025	300,000	$	30,000	1,000,000	$	100,000	$	130,000
Issuance of Series A preferred units, net of issuance costs and fair value of Warrant	—	—		1,200,000	121,798		121,798
Redemption of Series A preferred units	—	—		(1,000,000)	(100,000)		(100,000)
Preferred dividends attributable to redeemable non-controlling interest	—	1,154		—	4,865		6,019
Preferred dividends attributable to Class A common stockholders	—	243		—	1,023		1,266
Payment of preferred dividends	—	(1,397)		—	(5,888)		(7,285)
Accretion to redemption value	—	—		—	6,602		6,602
Balance, June 30, 2026	300,000	$	30,000	1,200,000	$	128,400	$	158,400

Terms of Redeemable Preferred Units

The Series A-1 preferred units held by Hillman RNG Investments LLC (Hillman), Series A preferred units previously held by NextEra affiliated entity and the new Series A preferred units (collectively the “Preferred Units”) held by Preferred Fuels, have substantially the same terms and features (unless specified otherwise) which are listed below:

Voting: The Series A-1 preferred units do not have any voting rights. The Series A preferred units carry no voting rights except as required by Delaware law or as provided under certain protective covenants in the Subscription Agreement.

Dividends: The Series A-1 preferred units are entitled to receive dividends at a rate of 12% per annum. The Series A preferred units are entitled to preferred quarterly distributions at a rate of 12% per annum (“Preferred Coupon”), compounding quarterly. Dividends on each series begin accruing from the issuance date, are mandatory and cumulative. OPAL Fuels may elect to pay up to 2% per annum of the 12% Series A Preferred Coupon in kind through the issuance of additional Series A preferred units.

Liquidation preference: In the event of a liquidation of OPAL Fuels, each holder of Series A and Series A-1 units is entitled to receive, on a pro rata basis, the original issue price of $100 per unit plus any accrued and unpaid dividends, out of assets available for distribution after payment of debt, liabilities, and liquidation expenses.

Redemption and Conversion: OPAL Fuels may redeem each series of Preferred Units at any time at the original issue price of $100 per unit plus accrued and unpaid dividends. Under the Series A preferred units, the Company was required to respond within 90 days from the date of the holder’s redemption notice in accordance with the applicable terms.

Preferred Fuels may require redemption upon (i) a change of control, (ii) an uncured material debt default or breach of protective covenants continuing for 60 days, or (iii) at any time on or after the fifth anniversary of the initial closing (March 6, 2031). In the event OPAL Fuels fails to redeem the Series A preferred units when requested: (1) the Preferred Coupon rate increases by an additional 0.50% per quarter, subject to a maximum of 4.00% per annum above the then-applicable rate, with all accrued distributions compounding quarterly at the Preferred Coupon plus the penalty rate; and (2) any residual cash flow of OPAL Fuels and its subsidiaries after operating expenses and capital expenditures must be applied to redeem the Series A preferred units at the applicable Redemption Price until the failure is cured. The applicable Redemption Price is (i) a price equal to at least 1.15 times the original issue price (inclusive of all fees paid and accrued dividends) on or prior to the first anniversary of the initial closing, (ii) 102% of the original issue price (exclusive of fees) after the first but on or prior to the second anniversary, and (iii) the original issue price plus accrued and unpaid cash dividends thereafter. Preferred Fuels also has the right, but not the obligation, to appoint a single director to the Board of Directors of OPAL Fuels Inc. if the redemption failure is not cured within 90 days.

9. NET (LOSS) INCOME PER SHARE

The following table summarizes the calculation of basic and diluted net (loss) income per share:


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Net (loss) income attributable to Class A common stockholders basic and diluted	$	(1,501)	$	800	$	(4,143)	$	565

Weighted average number of shares of Class A common stock - basic	29,641,216		28,265,710		28,966,490		27,995,258

Weighted average number of shares of Class A common stock - diluted	29,641,216		29,229,245		28,966,490		28,688,505
Net (loss) income per share of Class A common stock
Basic	$	(0.05)	$	0.03	$	(0.14)	$	0.02
Diluted	$	(0.05)	$	0.03	$	(0.14)	$	0.02

The basic (loss) income per share for the three and six months ended June 30, 2026 and 2025 does not include 1,635,783 shares in treasury and 716,650 shares that are issued and outstanding but are contingent on achieving earnout targets.

Additionally, the diluted (loss) income per share of Class A common stock for the three and six months ended June 30, 2026 and 2025 does not include redeemable preferred non-controlling interests because the substantive contingency for conversion has not been met as of June 30, 2026. It also excludes redeemable non-controlling interests for the three and six months ended June 30, 2026 and 2025.

For the periods in which (loss) income per share is presented, the following securities were excluded from the computation of diluted (loss) income per share since their impact would have been antidilutive:


	Six Months Ended June 30,
		2026	2025
Stock Options		1,237,505	483,502
Unvested PSUs (1)		2,654,994	2,015,403
Unvested RSUs		4,760,151	1,104,068
Warrants (2)		2,160,000	—
OPAL Fuels Class B Units		144,399,037	144,399,037

(1) All unvested PSUs are contingent on achieving performance targets.

(2) Includes 720,000 warrants that are subject to forfeiture contingent on obtaining additional funding.

10. INCOME TAXES

For the three and six months ended June 30, 2026, the Company recorded $4,738 and $10,447 income tax benefit, respectively, as a result of the generation of 45z credits. The Company also sold ITCs to a buyer for proceeds of $9,563, net of transaction costs, in March 2026.

For the three and six months ended June 30, 2025, the Company recorded $13,686 and $21,723 income tax benefit, respectively, as a result of the generation and sale of ITC credits.

The Company evaluates the realizability of the deferred tax assets on a quarterly basis and establishes a valuation allowance when it is more likely than not that all or a portion of a deferred tax asset may not be realized. The estimated Section 45Z credits reflect management's current assumptions regarding prevailing wage compliance. The Company continues to evaluate compliance requirements and will adjust its estimates, if necessary, as additional information becomes available.

11. STOCK-BASED COMPENSATION

The Company adopted 2022 Omnibus Equity Incentive Plan (the "2022 Plan") in 2022 which was approved by our stockholders on July 21, 2022. The purposes of the 2022 Plan are to (i) provide an additional incentive to selected employees, directors, and independent contractors of the Company or its Affiliates whose contributions are essential to the growth and success of the Company, (ii) strengthen the commitment of such individuals to the Company and its Affiliates, (iii) motivate those individuals to faithfully and diligently perform their responsibilities and (iv) attract and retain competent and dedicated individuals whose efforts will result in the long-term growth and profitability of the Company. The 2022 Plan allows for granting of stock options, stock appreciation rights, restricted stock, restricted stock units and other stock-based awards. The Company registered 19,811,726 shares of Class A common stock that can be issued under this Plan. The stock-based compensation expense for the above stock awards under the 2022 Plan as well as Parent Equity Awards is included in the selling, general and administrative expenses:


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
2022 Plan	$	2,060	$	2,205	$	4,115	$	3,827
Parent equity awards	—		—		—		129
Total	$	2,060	$	2,205	$	4,115	$	3,956

12. COMMITMENTS AND CONTINGENCIES

Letters of Credit

As of June 30, 2026 and December 31, 2025, the Company was required to maintain standby letters of credit totaling $31,674 and $15,504, respectively, to support obligations of certain Company's subsidiaries. These letters of credit were issued in favor of a lender, utilities, a governmental agency, and an independent system operator under PPA electrical interconnection agreements, and in place of a debt service reserve. There have been no draws to date on these letters of credit.

Lease Commitments

The table below provides the total amount of lease payments on an undiscounted basis on our lease contracts as of June 30, 2026:


	Operating Leases		Finance Leases		Total
Six months ending December 31, 2026	$	815	$	633	$	1,448
2027	1,673		1,030		2,703
2028	1,180		462		1,642
2029	1,129		112		1,241
2030	1,129		71		1,200
Thereafter	18,667		—		18,667
Total undiscounted cashflows	$24,593		$2,308		$26,901

Guaranty

On March 30, 2026, Land2Gas LLC, a 50%-owned equity method investee, sold $22,926 of investment tax credits to Athene Annuity and Life Company and Athene Annuity Re II Ltd. for net proceeds of $21,550, of which the Company's 50% share was $10,775. Land2Gas LLC is obligated to return the purchase price and reimburse any taxes, interest, and penalties if the credits are disallowed or recaptured.

The Company and an unaffiliated third party (together, the "Guarantors") each guarantee 50% of these obligations and have entered into a cross-indemnification agreement allocating losses attributable to each party's respective causation. The guarantees include credit support provisions whereby, upon specified credit-related events — including either Guarantor's

net worth falling below defined thresholds — the applicable Guarantor may be required to provide letters of credit or cash collateral to the buyers.

The Company's maximum potential exposure represents its 50% proportionate share of the purchase price repayment and related tax indemnification obligations. The Company evaluated these arrangements under ASC 460 and ASC 450 and determined that no material liability was required to be recognized as of June 30, 2026.

Legal Matters

Direct Contractor Claims

In September 2021, an indirect subsidiary of the Company, MD Digester, LLC (“MD”), entered into a fixed-price Engineering, Procurement and Construction Contract (an “EPC Contract”) with VEC Partners, Inc. d/b/a CEI Builders (“CEI”) for the design and construction of a turn-key renewable natural gas production facility using dairy cow manure as feedstock in California’s Central Valley. In December 2021, a second indirect subsidiary of the Company, VS Digester, LLC (“VS”) entered into a nearly identical EPC Contract (collectively, the "EPC Contracts") for the design and construction of a second facility, also in California’s Central Valley. CEI’s performance under both of the EPC Contracts is fully bonded by licensed sureties.

CEI has submitted a series of change order requests seeking to increase the EPC Contract Price by approximately $14,000, per project, primarily due to: (1) modifications to CEI’s design drawings which are required to meet its contracted performance guaranties, and (2) a default by one of CEI’s major equipment manufacturers. The Company disputes the vast majority of the change order requests.

In January 2024, the Company filed a civil lawsuit captioned, MD Digester, LLC. et. al. vs. VEC Partners, Inc. et. al.; with the California Superior Court, County of San Joaquin; Action No. STK- CV-UCC-2024-0000185 and commenced a related arbitration proceeding in order to obtain a formal determination on the claims; American Arbitration Association ("AAA") Case No. 01-24-0000-0775. The Superior Court Action has been stayed, pending the conclusion of the arbitration. In the meantime, the AAA has empaneled three experienced arbitrators and has set the hearing date for the matter, currently scheduled in May 2027.

The EPC Agreement requires that CEI, continue working during the course of the litigation and related arbitration proceedings; however, CEI effectively stopped working. On June 26, 2024, MD issued a Notice of Default and Demand to Cure to CEI. CEI failed to do so, and on July 30, 2024, MD terminated CEI for default. MD notified CEI’s performance bond surety, Atlantic Specialty Insurance Company (Atlantic) of the termination and demanded that it perform under the bond. Atlantic has denied the claim.

Similarly, on July 11, 2024, VS issued a Notice of Default and Demand to Cure, advising CEI of its defaults and giving it an opportunity to cure. CEI failed to do so, and on August 27, 2024, VS terminated CEI for default. VS has notified CEI’s bond surety, also Atlantic, of the second termination and demanded that it perform under the bond. The surety has denied the claim.

As a result of CEI’s default and Atlantic’s denial of the claims, MD and VS have amended their claims in the AAA arbitration to include breach of contract claims against CEI and breach of performance bond claims against Atlantic (who was formally joined into the arbitration on November 20, 2024) in the AAA Arbitration with CEI.

CEI has since recorded mechanic’s liens against each of the projects for $4,948 (MD) and $1,984 (VS), and recently filed actions with the Stanislaus and San Joaquin County Superior Courts, respectively, to enforce their liens. It is expected that these claims will be stayed and consolidated with the pending arbitration proceeding.

The AAA proceeding is scheduled for evidentiary hearing from May 3 through June 7, 2027. Based upon the deposition testimony and the expert reports that were exchanged on February 23, 2026, the Company reasonably believes that it will demonstrate that the terminations were justified and for cause. Issues related to damages, i.e., the cost to complete the projects, are evolving and it is premature to offer an opinion on the strength of this component of the case.

Subcontractor Lien Claims

In addition to the above-referenced action and arbitration, several of CEI’s subcontractors have recorded mechanic’s liens against the MD and VS projects for $3,141, which the Company is obligated to defend and indemnify the dairy

owners from and against. Several of liens were untimely and have been released voluntarily by the claimants, others were released through the recording of release bonds by Company.

The NWP Industries, L.P. ("NWP") and Argo Sales ("Argo") claims have been settled and will be dismissed as to MD and VS when the settlement payments have been fully funded.

Former Development Partner/Construction Manager

In March 2024, the Company filed an action in the Orange County Superior Court (Case No. 30- 2024-01415510-CU-BC-CXC) against its former development partner and construction manager, Sierra Renewable Organics Management, LLC, as well as its principal (Ethan Werner) and affiliated engineering firm (CH Four Biogas) for Breach of Contract, Indemnity, Declaratory Relief, Intentional Misrepresentation and Negligent Misrepresentation relating to the design and development of the Projects. The defendants have recently filed an answer and certain cross claims. Discovery in the case is now underway.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

In this Management's Discussion and Analysis of Financial Condition and Results of Operations section, references to "OPAL," "we," "us," "our," and the "Company" refer to OPAL Fuels Inc. and its consolidated subsidiaries. The following discussion and analysis should be read in conjunction with our unaudited condensed consolidated financial statements as of June 30, 2026 and for the three and six months ended June 30, 2026 and 2025, and the audited consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the fiscal year ended December 31, 2025, as filed with the SEC on March 16, 2026. In addition to historical information, this discussion and analysis includes certain forward-looking statements which reflect our current expectations. The Company's actual results may materially differ from these forward-looking statements.

Overview

Opal Fuels Inc. (the "Company", "Opal", "we", "our" and "us") is a vertically integrated leader in the capture and conversion of biogas into low carbon intensity Renewable Power and RNG. We are also a leader in the marketing and distribution of RNG to heavy duty trucking and other hard to de-carbonize industrial sectors. RNG is chemically identical to the natural gas used for cooking, heating homes and fueling natural gas engines, with one significant difference: RNG is produced by recycling methane emissions created by decaying organic waste as opposed to natural gas which is a fossil fuel pumped from the ground. We have participated in the biogas-to-energy industry for over 20 years.

Biogas is generated by microbes as they break down organic matter in the absence of oxygen, and comprised of non-fossil waste gas, with high concentrations of methane, which is the primary component of RNG and the source for combustion utilized by Renewable Power plants to generate electricity. Biogas can not only be collected and processed to remove impurities for use as RNG (a form of high-Btu fuel) and injected into existing natural gas pipelines as it is fully interchangeable with fossil natural gas, but partially treated biogas can be used directly in heating applications (as a form of medium-Btu fuel) or in the production of Renewable Power. Our principal sources of biogas are (i) LFG, which is produced by the decomposition of organic waste at landfills, and (ii) dairy manure, which is processed through anaerobic digesters to produce the biogas.

We also design, develop, construct, operate and service Fueling Stations for trucking fleets across the country that use natural gas to displace diesel as their transportation fuel. We have participated in the alternative vehicle fuels industry for over a decade and have established an expanding network of Fueling Stations for dispensing RNG. In addition, we have recently begun implementing design, development, and construction services for hydrogen Fueling Stations, and we are pursuing opportunities to diversify our sources of biogas to other waste streams.

Critical Accounting Policies and Estimates

The discussion and analysis of our financial condition and results of operations is based upon our interim unaudited condensed consolidated financial statements, which have been prepared in accordance with generally accepted accounting principles in the United States ("U.S. GAAP") and the rules and regulations of the SEC, which apply to interim financial statements. The preparation of those financial statements requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities, revenues, costs and expenses and related disclosure of contingent assets and liabilities at the date of our financial statements. Actual results may differ from these estimates under different assumptions and conditions.

Critical accounting policies are those that reflect significant judgments of uncertainties and potentially result in materially different results under different assumptions and conditions. For a detailed description of all our accounting policies, see Note 1. Summary of Significant Accounting Policies, to our condensed consolidated financial statements included herein and the section titled “Critical Accounting Policies and Estimates” contained in Part II, Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2025. There have been no material changes to our critical accounting policies since our Annual Report on Form 10-K for the year ended December 31, 2025.

Key Factors and Trends Influencing our Results of Operations

The principal factors affecting our results of operations and financial condition are the markets for RNG, Renewable Power, and associated Environmental Attributes, access to suitable biogas production resources, the regulatory environment of our industry, and the seasonality of demand and pricing for our products. Additional factors and trends affecting our business are discussed in "Risk Factors" within our Annual Report on Form 10-K for the year ended December 31, 2025.

Market Demand for RNG

Demand for our converted biogas and associated Environmental Attributes, including RINs and LCFS credits, is heavily influenced by United States federal and state energy regulations together with commercial interest in renewable energy products. Markets for RINs and LCFS credits arise from regulatory mandates that require refiners and blenders to incorporate renewable content into transportation fuels. The EPA annually sets proposed renewable volume obligations ("RVOs") for D3 RINs in accordance with the mandates established by the Energy Independence and Security Act of 2007. In March 2026, the EPA set RVOs for 2026 through 2027. On the state level, the economics of RNG are enhanced by low-carbon fuel initiatives, particularly well-established programs in California, Washington and Oregon (with several other states also actively considering LCFS initiatives similar to those in California, Washington and Oregon). Federal and state regulatory developments could result in significant future changes to market demand for the RINs and LCFS credits we produce. This would have a corresponding impact to our revenue, net income, and cash flow.

Transportation, including heavy-duty trucking, generates approximately 30% of overall carbon dioxide and other climate-harming GHG emissions in the United States, and transitioning this sector to low and negative carbon fuels is a critical step towards reducing overall global GHG emissions. The adoption rate of RNG-powered vehicles by commercial transportation fleets will significantly impact demand for our products.

We are also exposed to the commodity prices of natural gas and diesel, which serve as alternative fuel for RNG and therefore impact the demand for RNG.

Renewable Power Markets

We also generate revenues from sales of Renewable Power generated by our biogas-to-Renewable Power projects, and associated RECs. RECs exist because of legal and governmental regulatory requirements in Europe and the United States, and a change in law or in governmental policies concerning Renewable Power, LFG, or RECs could affect the market for, and the pricing of, such power and credits.

We periodically evaluate opportunities to convert existing Renewable Power projects to RNG production. We have been negotiating with several of our landfill and Renewable Power counterparties to enter into arrangements that would enable the LFG resource to produce RNG. Changes in the price we receive for Renewable Power and associated RECs, together with the revenue opportunities and conversion costs associated with converting our LFG sites to RNG production, could have a significant impact on our future profitability.

Regulatory landscape

We operate in an industry that is subject to and currently benefits from environmental regulations. Government policies can increase demand for our products by providing incentives to purchase RNG and Environmental Attributes. These government policies are modified and in flux constantly and any adverse changes to these policies could have a material effect on the demand for our products. For more information, see our risk factor titled "The financial performance of our business depends upon tax and other government incentives for the generation of RNG and Renewable Power, any of which could change at any time and such changes may negatively impact our growth strategy." within our Annual Report on Form 10-K for the year ended December 31, 2025. Government regulations have become increasingly stringent and complying with changes in regulations may result in significant additional operating expenses.

Seasonality

We experience seasonality in our results of operations. Sale of RNG may be impacted by higher consumption by some of our customers during summer months. Additionally, the price of RNG is higher during the fall and winter months due to increase in overall demand for natural gas during the winter months. Revenues generated from our renewable electricity projects in the northeast U.S., all of which sell electricity at market prices, are affected by warmer and colder weather, and therefore a portion of our quarterly operating results and cash flows are affected by pricing changes due to regional temperatures. These seasonal variances are managed in part by certain off-take agreements at fixed prices.

Key Components of Our Results of Operations

We generate revenues from the sale of RNG Fuel, Renewable Power, and associated Environmental Attributes, as well as from the construction, fuel supply, and servicing of Fueling Stations for commercial transportation vehicles using

natural gas to power their fleets. These revenue sources are presented in our consolidated statements of operations under the following captions:

•RNG Fuel. The RNG Fuel segment includes RNG supply as well as the associated generation and sale of commodity natural gas and environmental credits, and consists of:

◦RNG Production Facilities – the design, development, construction, maintenance and operation of facilities that convert raw biogas into pipeline quality natural gas; and

◦Our interests in both operating and construction projects.

•Fuel Station Services. Through the Fuel Station Services segment, we provide construction and maintenance services to third-party owners of vehicle Fueling Stations and perform fuel dispensing activities including generation and minting of environmental credits. This segment includes:

◦Manufacturing division that builds compact fueling systems and defueling systems;

◦Design/Build contracts where the Company serves as general contractor for construction of Fueling Stations, typically structured as Guarantee Maximum Price or fixed priced contracts for customers, generally lasting less than one year;

◦Service and maintenance contracts for RNG/CNG Fueling Stations; and

◦RNG and CNG Fuel Dispensing Stations - This includes both the dispensing (or sale) of RNG, CNG, and environmental credit generation and monetization. We operate Fueling Stations that dispense both CNG and RNG fuel for vehicles.

•Renewable Power Portfolio. The Renewable Power segment generates Renewable Power and associated Environmental Attributes through combustion of biogas from landfills which is then sold to public utilities throughout the United States. Please see Note 7. Reportable Segments and Geographic Information to our condensed consolidated financial statements for additional information.

Our costs of sales associated with each revenue category are as follows:

•RNG Fuel. Includes royalty payments to biogas site owners for the biogas we use; service provider costs; salaries and other indirect expenses related to the production process, utilities, transportation, storage, and insurance; and depreciation of production facilities.

•Fuel Station Services. Includes equipment supplier costs; service provider costs; and salaries and other indirect expenses.

•Renewable Power. Includes land usage costs; service provider costs; salaries and other indirect expenses related to the production process; utilities; and depreciation of production facilities.

Project development and startup costs includes certain development costs such as legal fees, consulting fees for joint venture structuring, royalties to the landfill owner, fines, settlements, site lease expenses and certification costs on our RNG projects under construction. Additionally, we also incur certain expenses on new RNG projects during the first two years that such projects are operational, such as virtual pipeline costs (incurred until a physical interconnect pipeline is built) and ramp up costs incurred during the certification period.

Selling, general, and administrative expense consists of costs involving corporate overhead functions, including the cost of services provided to us by an affiliate, and marketing costs.

Depreciation and amortization primarily relate to depreciation associated with property, plant, and equipment and amortization of acquired intangibles arising from PPAs and interconnection contracts. We are in the process of expanding our RNG and Renewable Power production capacity and expect depreciation costs to increase as new projects are placed into service.

Concentration of customers and associated credit risk

The following table summarizes the percentage of consolidated accounts receivable, net by customers that equal or exceed 10% of the consolidated accounts receivable, net as of June 30, 2026 and December 31, 2025. No other single customer accounted for 10% or greater of our consolidated accounts receivables in these periods:


	June 30, 2026		December 31, 2025
Customer A (1)	21	%	21	%
Customer B	21	%	11	%
Customer C	*		12	%
Customer D	*		19	%

(1) Relates to sales of Environmental Attributes under Purchase and Sale agreements and Renewable Power sale agreements.

*Less than 10%

The following table summarizes the percentage of consolidated revenues from customers that equal 10% or greater of the consolidated revenues in the period. No other single customer accounted for more than 10% of consolidated revenues in these periods:


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Customer A	45	%	37	%	42	%	39	%

*Less than 10%

Results of operations for the three and six months ended June 30, 2026 and 2025:

Operational data

The following table summarizes the operational data achieved for the three and six months ended June 30, 2026 and 2025:

Landfill RNG Facility Capacity and Utilization Summary


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Design Capacity (Million MMBtus) (1)	2.2		2.1		4.4		4.3
Volume of Inlet Gas (Million MMBtus) (2)	1.6		1.6		3.1		3.0
Inlet Design Capacity Utilization % (2)	75.2	%	76.3	%	73.5	%	72.5	%
RNG Fuel volume produced (Million MMBtus) (3)	1.2		1.1		2.4		2.2
Utilization of Inlet Gas % (4)	76.6	%	75.0	%	76.0	%	75.8	%

(1) Design Capacity for RNG facilities is measured as the volume of feedstock biogas that the facility is capable of accepting at the inlet and processing during the associated period. Design Capacity is presented as our ownership share (i.e., net of joint venture partners’ ownership) of the facility and is calculated based on the number of days in the period. New facilities that come online during a quarter are pro-rated for the number of days in commercial operation.

(2) Inlet Design Capacity Utilization is measured as the Volume of Inlet Gas for a period, divided by the total Design Capacity for such period. The Volume of Inlet Gas varies over time depending on, among other factors, (i) the quantity and quality of waste deposited at the landfill, (ii) waste management practices by the landfill, and (iii) the construction, operations and maintenance of the LFG collection system used to recover the LFG. The Design Capacity for each facility will typically be correlated to the amount of LFG expected to be generated by the landfill during the term of the related gas rights agreement. We expect Inlet Design Capacity Utilization to be in the range of 75-85% on an aggregate basis over the next several years. Typically, newer facilities perform at the lower end of this range and demonstrate increasing utilization as they mature and the biogas resource increases at open landfills. Excludes Sunoma and Biotown.

(3) Excludes Sunoma and Biotown

(4) Utilization of Inlet Gas is measured as RNG Fuel Volume Produced divided by the Volume of Inlet Gas. Utilization of Inlet Gas varies over time depending on availability and efficiency of the facility and the quality of LFG (i.e., concentrations of methane, oxygen, nitrogen, and other gases). We generally expect Utilization of Inlet Gas to be in the range of 80% to 90%. Excludes Sunoma and Biotown.

Renewable Power Capacity and Utilization Summary


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
Nameplate Capacity (MW per hour)(1)	100.2		105.8		100.2		105.8
Nameplate Capacity for the period (Millions MWh) (1)	0.22		0.23		0.44		0.46
Renewable Power produced (Millions MWh)	0.09		0.08		0.18		0.17
Design Capacity Utilization (%) (2)	39	%	35	%	40	%	37	%

(1) Nameplate Capacity for Renewable Power facilities is the manufacturer’s expected capacity at International Organization for Standardization conditions for each facility and may not reflect actual production from the projects, which depends on many variables including, but not limited to, (i) quantity and quality of the biogas, (ii) operational up-time of the facility, including dispatch and maintenance downtime and (iii) actual efficiency of the facility.

(2) Nameplate Capacity Utilization for Renewable Power facilities is measured as Renewable Power Produced divided by Design Capacity for the period. Given (i) built-in un-utilized capacity from historical designs, (ii) availability (a function of higher maintenance requirements compared to RNG facilities) and (iii) commencement of operations of the Emerald RNG facility, which will result in low levels of dispatch for the Arbor Hills facility (which will operate on a standby basis but remain in the operating portfolio), our Design Capacity Utilization is expected to remain below 50%.

RNG Projects

Below is a table setting forth the RNG projects in operation and construction in our portfolio as of June 30, 2026:


	OPAL's Share of Design Capacity (MMbtus per year) (1)	Source of Biogas	Ownership
RNG Projects in Operation:
Greentree	1,061,712	LFG	100%
Imperial	1,061,712	LFG	100%
Emerald (2)	1,327,140	LFG	50%
Sapphire (2)	796,284	LFG	50%
New River	663,570	LFG	100%
Noble Road (2)	464,499	LFG	50%
Pine Bend (2)	424,685	LFG	50%
Biotown (2)	41,274	Dairy	10%
Sunoma (3)	176,297	Dairy	90%
Prince William	1,725,282	LFG	100%
Polk County	1,061,712	LFG	100%
Atlantic (2)	331,785	LFG	50%
Total	9,135,952

RNG Projects in Construction:
Hilltop (4)	255,500	Dairy	100%
Vander Schaaf (4)	255,500	Dairy	100%
Burlington (2)	459,900	LFG	50%
Cottonwood	664,884	LFG	100%
Kirby Canyon	663,570	LFG	100%
Grady Road	530,000	LFG	100%
Stones Throw	390,000	LFG	100%
CMS	1,010,000	LFG	70%
Total	4,229,354

(1) Reflects the Company’s ownership share of design capacity for projects that are not 100% owned by the Company (i.e., net of joint venture partners’ ownership). Design capacity is measured as the volume of feedstock biogas that the plant is capable of accepting at the inlet and processing and may not reflect actual production of RNG from the projects, which will depend on many variables including, but not limited to, (i) quantity and quality of the biogas, (ii) operational up-time of the facility and (iii) actual efficiency of the facility.

(2) We record our ownership interests in these projects as equity method investments in our consolidated financial statements.

(3) This project has provisions that will adjust or “flip” the percentage of distributions to be made to us over time, typically triggered by achievement of hurdle rates that are calculated as internal rates of return on capital invested in the project.

(4) Please see Part II, Item 1: Legal Proceedings and Note 12. Commitments and Contingencies.

(5) The construction of the Cottonwood, Burlington and Kirby Canyon projects began in the second, third and fourth quarters of 2024, respectively.

(6) Expected Commercial Operation Date (“COD”) for commencement of the RNG projects in construction is based on the Company’s estimate as of the date of this report. CODs are estimates and are subject to change as a result of, among other factors out of the Company’s control: (i) regulatory/permitting approval timing, (ii) disruption in supply chains and (iii) construction timing.

RNG Fuel Production, Sales, and Delivery


	Three Months Ended June 30,		Six Months Ended June 30,
	2026	2025	2026	2025
RNG Fuel volume produced (Million MMBtus)	1.3	1.2	2.4	2.3
RNG Fuel volume sold (Million GGEs)	20.9	20.6	38.8	40.1
Total volume delivered (Million GGEs)	39.0	40.8	78.0	81.4

Comparison of the three and six months ended June 30, 2026 and 2025

The following table presents the period-over-period change for each line item in our condensed consolidated statements of operations for the three and six months ended June 30, 2026 and 2025.


	Three Months Ended June 30,				$ Change		% Change		Six Months Ended June 30,				$ Change		% Change
(in thousands)	2026		2025						2026		2025
Revenues:
RNG fuel	$	23,821	$	25,130	$	(1,309)	(5)	%	$	45,459	$	52,729	$	(7,270)	(14)	%
Fuel Station Services	53,064		47,026		6,038		13	%	97,630		97,704		(74)		—	%
Renewable Power	6,514		8,300		(1,786)		(22)	%	13,685		15,430		(1,745)		(11)	%
Total revenues	83,399		80,456		2,943		4	%	156,774		165,863		(9,089)		(5)	%
Operating expenses:
Cost of sales - RNG fuel	12,282		11,414		868		8	%	25,111		23,567		1,544		7	%
Cost of sales - Fuel station services	40,362		38,731		1,631		4	%	75,752		78,453		(2,701)		(3)	%
Cost of sales - Renewable power	6,285		6,899		(614)		(9)	%	11,915		13,661		(1,746)		(13)	%
Project development and startup costs	3,301		3,477		(176)		(5)	%	5,116		9,558		(4,442)		(46)	%
Selling, general and administrative	14,274		17,460		(3,186)		(18)	%	29,458		33,427		(3,969)		(12)	%
Depreciation, amortization, and accretion	5,167		5,264		(97)		(2)	%	10,780		11,206		(426)		(4)	%
Impairment loss	4,142		—		4,142		100	%	4,142		—		4,142		100	%
Loss (income) from equity method investments	597		(1,962)		2,559		130	%	2,354		(1,240)		3,594		290	%
Total operating expenses	86,410		81,283		5,127		6	%	164,628		168,632		(4,004)		(2)	%
Operating loss	(3,011)		(827)		(2,184)		(264)	%	(7,854)		(2,769)		(5,085)		(184)	%
Other expense
Interest and financing expense	(8,647)		(6,637)		(2,010)		(30)	%	(15,291)		(13,087)		(2,204)		(17)	%
Interest income	2,101		270		1,831		678	%	2,861		655		2,206		337	%
Other income, net	672		1,067		(395)		(37)	%	97		2,321		(2,224)		(96)	%
Net loss before income tax benefit	(8,885)		(6,127)		(2,758)		(45)	%	(20,187)		(12,880)		(7,307)		(57)	%
Income tax benefit	4,738		13,686		(8,948)		(65)	%	10,447		21,723		(11,276)		(52)	%
Net (loss) income	(4,147)		7,559		(11,706)		(155)	%	(9,740)		8,843		(18,583)		(210)	%
Net (loss) income attributable to redeemable non-controlling interest	(7,136)		3,982		(11,118)		(279)	%	(19,703)		2,808		(22,511)		(802)	%
Net income attributable to non-redeemable non-controlling interest	137		160		(23)		(14)	%	219		236		(17)		(7)	%
Accretion of the redeemable preferred non-controlling interest to its redemption amount	4,353		2,617		1,736		66	%	13,887		5,234		8,653		165	%

Net (loss) income attributable to Class A common stockholders	$	(1,501)	$	800	$	(2,301)	(288)	%	$	(4,143)	$	565	$	(4,708)	(833)	%

Revenues


	Three Months Ended June 30,						Six Months Ended June 30,
(in thousands)	2026		2025		$ Change		2026		2025		$ Change
RNG Fuel
Environmental attributes	$	20,424	$	19,941	$	483	$	38,654	$	45,771	$	(7,117)
Brown gas sales and other	3,397		5,189		(1,792)		6,805		6,958		(153)
Total RNG Fuel	23,821		25,130		(1,309)		45,459		52,729		(7,270)
Fuel Station Services
OPAL owned stations	5,102		5,916		(814)		11,053		10,822		231
Environmental attributes and RNG marketing (1)	30,994		22,774		8,220		52,183		51,300		883
Third party station service and maintenance	7,125		6,534		591		13,925		13,604		321
Construction	6,329		9,183		(2,854)		11,228		17,174		(5,946)
Lease revenues (2)	3,514		2,619		895		9,241		4,804		4,437
Total Fuel Station Services	53,064		47,026		6,038		97,630		97,704		(74)
Renewable Power
Electricity sales	4,915		4,324		591		10,707		9,580		1,127
Environmental attributes	1,158		2,767		(1,609)		1,871		3,588		(1,717)
Lease revenues (3)	190		391		(201)		422		647		(225)
Other (4)	251		818		(567)		685		1,615		(930)
Total Renewable Power	6,514		8,300		(1,786)		13,685		15,430		(1,745)

Total revenues	$	83,399	$	80,456	$	2,943	$	156,774	$	165,863	$	(9,089)

Revenue from contracts with customers	$	79,695	$	77,446	$	2,249	$	147,111	$	160,412	$	(13,301)
Revenue from lease arrangements	$	3,704	$	3,010	$	694	$	9,663	$	5,451	$	4,212

(1) Revenues from RNG marketing in the Fuel Station Services segment relate to revenues earned from Environmental Attribute generation and monetization services.

(2) Fuel Station Services lease revenue relates to revenue from fuel purchasing agreements where we determined that we transferred the right to control the use of the station to the purchaser. Includes sales-type lease revenues of $—, $—, $2,246, and $—for the three months ended June 30, 2026 and 2025, and the six months ended June 30, 2026 and 2025, respectively, from customers domiciled outside of the United States. All remaining lease revenue relates to operating leases.

(3) Renewable Power operating lease revenue relates to revenue from power purchase agreements where we determined that we transferred the right to control the use of the power plant to the purchaser.

(4) Includes management fee revenues earned from management of operations of equity method entities.

RNG Fuel

Revenue from RNG Fuel decreased by $1.3 million or 5% for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. This decrease was primarily due to a reduction in unrealized mark-to-market gains associated with brown gas marketing and trading activities of $1.8 million, offset by increase in environmental attributes of $0.5 million.

Revenue from RNG Fuel decreased by $7.3 million, or 14%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. This decrease was primarily related to $7.3 million decrease in the sale of environmental attributes. The decrease in environmental attributes was primarily related to $4.5 million decrease in RIN volume, $1.6 million decrease in green gas sales and a $1.2 million decrease due to lower LCFS sales.

Fuel Station Services

Revenue from Fuel Station Services increased by $6.0 million or 13%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. The increase was primarily attributable to an $6.5 million increase in LCFS credit sales, a $1.6 million increase resulting from higher RIN volumes, a $0.1 million increase due to higher RIN

prices, a $0.9 million increase in lease revenue, $0.4 million increase from higher tolling GGEs and a $0.6 million increase in third-party service revenue due to higher service rates. These increases were partially offset by a $2.9 million decrease attributable to delays in construction projects and a $1.2 million decrease resulting from eliminations.

Revenue from Fuel Station Services decreased by $0.1 million, or —%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. This change was primarily attributable to a $5.9 million decrease in construction revenue due to project timing, a $0.5 million decrease resulting from lower RIN volumes, and a $0.4 million decrease due to lower RIN prices. These decreases were partially offset by a $4.4 million increase in lease revenue, a $1.7 million increase in RIN and LCFS minting revenue, a $0.3 million increase in service revenue driven by higher GGE volumes and service rates, and a $0.2 million increase attributable to higher GGE volumes at OPAL-owned stations.

Renewable Power

Revenue from Renewable Power decreased by $1.8 million, or 22%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. The decrease was primarily driven by a $1.7 million decline in environmental attribute revenue, primarily at the West Covina facility.

Revenue from Renewable Power decreased by $1.7 million, or 11%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. The decrease was primarily attributable to a $1.7 million decline in environmental attribute revenue, primarily at the West Covina facility.

Cost of sales

RNG Fuel

Cost of sales from RNG Fuel increased by $0.9 million, or 8%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. The increase was primarily attributable to higher royalty expense of $0.5 million, primarily resulting from a first-quarter catch-up adjustment, higher non-labor and major maintenance costs of $0.5 million, and higher gas expense of $0.2 million. These increases were partially offset by a $0.4 million decrease in utility and labor costs.

Cost of sales from RNG Fuel increased by $1.5 million, or 7%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. The increase was primarily attributable to a $2.6 million increase in transportation and gas expense, a $0.3 million increase in utilities expense, and a $0.2 million increase in labor costs, partially offset by a $1.6 million decrease in royalty expense.

Fuel Station Services

Cost of sales from Fuel Station Services increased by 1.6 million, or 4%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. The increase was primarily attributable to a $5.1 million increase in dispensing fees and a $0.8 million increase in service-related labor and compensation costs, partially offset by a $3.1 million decrease in construction equipment, parts, and oil expense due to delays in project activity and a $1.1 million decrease in FPA tolling expense, reflecting a large FPA cost recognized in the prior-year period.

Cost of sales from Fuel Station Services decreased by $2.7 million, or 3%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. The decrease was primarily attributable to a $3.3 million decrease in construction costs resulting from project delays, and by a $0.5 million decrease in dispensing fees this is partially offset by a $1.1 million increase in service-related labor and compensation costs.

Renewable Power

Cost of sales from Renewable Power decreased by $0.6 million, or 9%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. The decrease was primarily attributable to a $0.7 million reduction in major maintenance expense and a $0.2 million decrease in labor costs. These decreases were partially offset by a $0.3 million increase in non-labor and other operating expenses due to the timing of expenditures.

Cost of sales from Renewable Power decreased by $1.7 million, or 13% for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. The decrease was primarily attributable to lower major maintenance expense of $1.5 million, primarily at two facilities, as well as a $0.2 million decrease in labor costs.

Project development and startup costs

Project development and startup costs decreased by $0.2 million, or 5%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. The decrease was primarily attributable to lower virtual pipeline costs, partially offset by higher project development and startup activities.

Project development and startup costs decreased by $4.4 million, or 46%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. The decrease was primarily attributable to lower virtual pipeline costs.

Selling, general, and administrative

Selling, general, and administrative expenses decreased by a total of $3.2 million, or 18%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. The decrease was primarily attributable to lower compensation costs of $1.8 million, information technology expenses of $0.5 million, directors' and officers' ("D&O") insurance expense of $0.5 million, and advocacy costs of $0.2 million.

Selling, general, and administrative expenses decreased by a total of $4.0 million, or 12%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. The decrease was primarily attributable to lower compensation costs of $1.1 million, legal expenses of $1.1 million, D&O insurance expense of $0.5 million, professional fees of $0.5 million, lower travel and entertainment of $0.3 million and other expenses of $0.5 million.

Depreciation, amortization, and accretion

Depreciation, amortization, and accretion decreased by a total of $0.1 million, or 2%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. This is primarily related to lower depreciation expense in Renewable Power.

Depreciation, amortization, and accretion decreased by a total of $0.4 million, or 4%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. The decrease was primarily attributable to lower depreciation expense resulting from the prior-year recognition of the remaining asset retirement obligation ("ARO") balance.

Impairment loss

Impairment loss increased by $4.1 million, or 100%, for the three and six months ended June 30, 2026 compared to the three and six months ended June 30, 2025. This was primarily attributable to impairment charges recorded on certain renewable energy facilities following strategic decisions to convert those facilities to RNG production operations.

Loss (income) from equity method investments

Net loss attributable to equity method investments increased by $2.6 million, or 130%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. This is primarily related to a decrease in the realized price of RINs sold on operating facilities and lower production primarily at Pine Bend and Emerald.

Net loss attributable to equity method investments increased by $3.6 million, or 290% for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. This is primarily related to a decrease in the realized price of RINs sold on operating facilities.

Interest and financing expense, net

Interest and financing expenses, net increased by $2.0 million, or 30%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. This is primarily related to an increase in the average outstanding loan balance.

Interest and financing expenses, net increased by $2.2 million, or 17%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. This is primarily related to an increase in the average outstanding loan balance.

Interest income

Interest income increased by $1.8 million or 678%, for the three months ended June 30, 2026 compared to the year ended June 30, 2025 primarily due to interest income from sales-type-lease.

Interest income increased by $2.2 million or 337%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025 primarily due to interest income from sales-type-lease.

Other income

Other income decreased by $0.4 million or 37% for the three months ended June 30, 2026 compared to the three months ended June 30, 2025 primarily related to change in fair value of warrants.

Other income decreased by $2.2 million, or 96%, for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. The decrease was primarily attributable to a gain on a note receivable and a gain from the write-off of a lease liability recognized during the 2025 period, with no comparable gains recognized in 2026.

Income tax benefit

Income tax benefit decreased by $8.9 million or 65% for three months ended June 30, 2026 compared to the three months ended June 30, 2025. This is primarily driven by lower generation of transferable tax credits in 2026 compared to 2025.

Income tax benefit decreased by $11.3 million or 52% for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. This is primarily driven by lower generation of transferable tax credits in 2026 compared to 2025.

Net (loss) income attributable to redeemable non-controlling interest

Net (loss) income attributable to redeemable non-controlling interest decreased by $11.1 million, or 279%, for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. The net (loss) income for the three months ended June 30, 2026 and 2025 reflects the portion of earnings belonging to OPAL Fuels equity holders. The decrease is primarily attributable to higher loss in the current period compared to the same prior-year period.

Net (loss) income attributable to redeemable non-controlling interest for the six months ended June 30, 2026 decreased by $22.5 million, or 802%, compared to the six months ended June 30, 2025. The decrease is primarily attributable to higher loss on the portion of earnings belonging to OPAL Fuels equity holders in the current period compared to the same prior-year period.

Net income attributable to non-redeemable non-controlling interest

Net income attributable to non-redeemable non-controlling interest remained flat for the three months ended June 30, 2026 compared to the three months ended June 30, 2025.

Net income attributable to non-redeemable non-controlling interest remained flat for the six months ended June 30, 2026, compared to six months ended June 30, 2025.

Accretion of the redeemable preferred non-controlling interest to its redemption amount

Accretion of the redeemable preferred non-controlling interest to its redemption amount increased by $1.7 million or 66% for the three months ended June 30, 2026 compared to the three months ended June 30, 2025. This is primarily driven by accretion to redemption value following the issuance of redeemable preferred non-controlling interests in March 2026.

Accretion of the redeemable preferred non-controlling interest to its redemption amount increased by $8.7 million or 165% for the six months ended June 30, 2026 compared to the six months ended June 30, 2025. This is primarily driven by accretion to redemption value following the issuance of redeemable preferred non-controlling interests in March 2026.

Liquidity and Capital Resources

Liquidity

As of June 30, 2026, our liquidity was $162.3 million, consisting of $19.3 million of unused capacity under the revolver, $51.6 million of undrawn preferred stock facility commitments and $91.4 million of cash and cash equivalents. Refer to Note 3. Loans.

We expect that our available cash together with our other assets, expected cash flows from operations, and access to expected sources of capital will be sufficient to meet our existing commitments for a period of at least twelve months from the date of this quarterly report. Any reduction in demand for our products or our failure to efficiently manage our production facilities may result in lower cash flows from operations which may impact our ability to make investments and may require changes to our growth plan.

To fund future growth, we anticipate seeking additional capital through equity or debt financings. The amount and timing of our future funding requirements will depend on many factors, including the pace and results of our project development efforts. We may be unable to obtain any such additional financing on acceptable terms or at all. Our ability to access capital when needed is not assured and, if capital is not available when, and in the amounts needed, we could be required to delay, scale back or abandon some or all of our development programs and other operations, which could materially harm our business, prospects, financial condition, and operating results.

As part of our operations, we have arrangements for office space for our corporate headquarters under the Administrative Services Agreement as well as operating leases for office space, warehouse space, and our vehicle fleet.

We intend to make payments under our various debt instruments when due and pursue opportunities for earlier repayment and/or refinancing if and when these opportunities arise. In the fourth quarter of 2025, NextEra exercised its redemption option to redeem the preferred units. The Units were redeemed in the first quarter of 2026. Refer to Note 8. Redeemable Non-controlling Interest, Redeemable Preferred Non-controlling Interest and Stockholders' Equity for additional details.

OPAL Term Loan

During the six months ended June 30, 2026, the Company drew $128.4 million under its term loan facility pursuant to its existing credit agreement. A portion of the proceeds from the borrowing was used to repay $20.0 million outstanding under the revolving loan facility. As of June 30, 2026, the Company had utilized $30.7 million of availability under the revolver loan to provide for the issuance of letters of credit to support the operations of the Borrower and the Guarantors.

During the six months ended June 30, 2026, the Company commenced principal payments under its credit agreement. In addition, beginning in the first quarter of 2026, the Company is subject to a quarterly cash sweep pursuant to which, within two business days after the required delivery of quarterly financial statements, a percentage of distributable cash is required to be applied to repay outstanding borrowings, with the applicable percentage determined based on the Company’s consolidated debt to cash flow ratio. If the required financial statements are not delivered within the specified timeframe, 100% of distributable cash is required to be applied to the cash sweep.

As of June 30, 2026 and December 31, 2025, the outstanding loan balance (current and non-current) excluding deferred financing costs was $421.6 million and $341.6 million, respectively.

We have the ability, during the delayed draw availability period, which expired in March 2026, and subject to the satisfaction of certain credit and project-related conditions precedent, to join other newly acquired subsidiaries with comparable renewable projects in development under the credit facility for comparable funding. As of June 30, 2026, we are in compliance with the financial covenants under the OPAL Term Loan.

On May 30, 2026, OPAL Fuels Inc. exercised its right pursuant to that certain Credit and Guarantee Agreement dated as of September 1, 2023 among Opal Fuels Intermediate HoldCo LLC as borrower (the "Borrower"), direct and indirect subsidiaries of the Borrower as guarantors, the lenders party thereto as lenders, and Bank of America, N.A., as administrative agent, to contribute approximately $8.0 million to the Borrower in order for the Borrower to maintain compliance with certain financial covenants under its credit facility.

Sunoma Loan

On August 27, 2020, Sunoma, an indirect wholly-owned subsidiary of ours entered into a debt agreement (the "Sunoma Loan Agreement") with Live Oak Banking Company for an aggregate principal amount of $20 million. Sunoma paid $0.6 million in financing fees. The amounts outstanding under the Sunoma Loan are secured by the assets of Sunoma. On July 19, 2022, Sunoma completed the conversion of the construction loan into a permanent loan and increased the commitment from $20.0 to $23.0 million. The maturity date is July 19, 2033. The outstanding loans under the Sunoma Loan Agreement bear interest at an annual fixed rates of 7.8% and 8.2% per annum during the term.

The Sunoma Loan Agreement contains certain financial covenants which require Sunoma to maintain (i) a maximum debt to net worth ratio not to exceed 5:1, (ii) a minimum current ratio not less than 1.0 and (iii) a minimum debt service coverage ratio of trailing four quarters not less than 1.25. As of June 30, 2026, Sunoma is in compliance with the financial covenants under the Sunoma Loan Agreement.

As of June 30, 2026 and December 31, 2025, the outstanding loan balance (current and non-current) excluding deferred financing costs was $18.2 million and $19.1 million, respectively.

The significant assets of Sunoma, as well as those of other consolidated variable VIEs, are presented in a separate table below the consolidated balance sheets as of June 30, 2026 and December 31, 2025. See Note 2. Investments in other entities and Variable Interest Entities for additional information.

Redeemable Series A Preferred Units of OPAL Fuels LLC

In November 2021, NextEra subscribed for an aggregate of $100.0 million of Series A preferred units issued by OPAL Fuels LLC, a consolidated subsidiary of OPAL Fuels, Inc.

On March 6, 2026, OPAL Fuels LLC (“Opal Fuels”), the Company’s primary operating consolidated subsidiary, entered into a subscription agreement (“Subscription Agreement”) with Preferred Fuels LLC, (“Preferred Fuels” or “Investor”), an entity under common control with the Company. Pursuant to the Subscription Agreement Preferred Fuels committed to purchase up to $180.0 million (the “Offering”) of Series A preferred units of Opal Fuels in multiple closings. At the initial closing on March 6, 2026, Preferred Fuels purchased 1,200,000 preferred units for aggregate proceeds of $120.0 million. OPAL Fuels may, in its sole discretion, require Preferred Fuels to fund up to an additional $60.0 million (or “Undrawn Commitment”) within one year of the initial closing (“or Availability Period”), subject to the terms of the Subscription Agreement. Additionally, pursuant to the Subscription Agreement, the Investor also has a right of first offer to purchase up to an additional 700,000 Units for an aggregate purchase price of up to $70.0 million in the Offering in the event that OPAL Fuels intends to sell any additional units prior to the two (2) year anniversary of the initial closing. Opal Fuels used the proceeds received from the issuance of the Series A preferred units on March 6, 2026 to redeem all of the previously issued and outstanding Series A preferred units held by NextEra.

Additionally, up to 840,000 shares issuable on a pro rata basis upon future purchases by Preferred Fuels of up to an additional 700,000 Series A preferred units (up to $70.0 million) within two years of the initial closing pursuant to its right of first offer. No Subsequent Warrant Shares have been issued as of June 30, 2026.

The Company recorded Series A preferred units as redeemable noncontrolling interest in its condensed consolidated financial statements at the amount of proceeds received, less the fair value of the Warrants of $2.8 million and directly attributable issuance costs of $3.8 million. The Series A preferred units are subsequently remeasured to their redemption value as of each reporting date as if such reporting date were the redemption date, with changes in carrying amount recorded as adjustments to additional paid-in capital to the extent available, with any excess recorded to accumulated deficit. The Company concluded that the Warrants are not indexed to the Company’s equity. The Warrants are accounted for as liabilities in the Company’s condensed consolidated financial statements with changes in fair value recognized in other income, net.

Terms of Redeemable Preferred Units

The Preferred Units held by Preferred Fuels, have substantially the same terms and features (unless specified otherwise) which are listed below:

As described in a Current Report on Form 8-K filed with the SEC on May 20, 2026, on May 18, 2026, OPAL Fuels approved and adopted an Amended and Restated Certificate of Designations of Series A-1 Preferred Units (the "A&R COD"), which amended and restated in its entirety that certain Certificate of Designations of Series A-1 Preferred Units OPAL Fuels, dated November 29, 2021. The A&R COD conforms the terms and conditions of OPAL Fuels' Series A-1 Preferred Units to those of OPAL Fuels' Series A Preferred Units in accordance with the Amended and Restated Certificate of Designations of Series A Preferred Units, which was approved and adopted by OPAL Fuels on March 6, 2026. The amendment increased the annual dividend rate from 8% to 12%, with only up to 2% payable in kind and the remainder payable in cash, revised certain redemption rights to permit holder redemption upon specified events including a change of control, certain uncured trigger events, or beginning on the fifth anniversary of March 6, 2026, and added enhanced holder protective provisions and remedies upon the occurrence of certain trigger events. The amendment also eliminated the holders' prior conversion rights upon delayed redemption of the preferred units .The A&R COD does not provide holders of Series A-1 Preferred Units with any rights to appoint members to the board of directors of the Company, which rights are provided to holders of Series A Preferred Units under the Amended and Restated Certificate of Designations of Series A Preferred Units.

Cash Flows

The following table presents our cash flows for the six months ended June 30, 2026 and 2025:


	Six Months Ended June 30,
(in thousands)	2026		2025
Net cash provided by operating activities	$	23,677	$	21,805
Net cash used in investing activities	(58,456)		(36,026)
Net cash provided by financing activities	101,653		18,498
Net increase in cash, restricted cash, and cash equivalents	$	66,874	$	4,277

Net Cash Provided by Operating Activities

Net cash provided by operating activities for the six months ended June 30, 2026 was $23.7 million, an increase of $1.9 million compared to $21.8 million for the six months ended June 30, 2025.

This was primarily attributable to favorable changes in working capital and income from investments in other entities, partially offset by higher net loss, lower noncash items and less distributions from return on investments in other entities.

Net Cash Used in Investing Activities

Net cash used in investing activities for the six months ended June 30, 2026 was $58.5 million, an increase of $22.4 million compared to the $36.0 million used in investing activities for the six months ended June 30, 2025.

This was primarily attributable to an increase in payments made for the construction of various RNG generation and dispensing facilities in 2026 compared to 2025, a decrease in distributions received from equity method investments and an increase in contributions made to equity method investments. These were partially offset by an increase in disposals of property, plant and equipment.

Net Cash Provided by Financing Activities

Net cash provided by financing activities for the six months ended June 30, 2026 was $101.7 million, an increase of $83.2 million compared to the net cash provided by financing activities of $18.5 million for the six months ended June 30, 2025.

This was primarily attributable to an increase in proceeds from long-term loans, an increase from the issuance of preferred stock and an increase in capital contribution from non-redeemable non-controlling interests. These were partially offset by redemption of shares of preferred stock, an increase in repayment of loans and an increase in cash paid to taxes related to net share settlement of equity awards.

Capital expenditures and other cash commitments

We require cash to fund our capital expenditures, operating expenses and working capital and other requirements, including costs associated with fuel sales; outlays for the design and construction of new Fueling Stations and RNG production facilities; debt repayments and repurchases; maintenance of our electrification production facilities supporting our operations, including maintenance and improvements of our infrastructure; supporting our sales and marketing activities, including support of legislative and regulatory initiatives; any investments in other entities; any mergers or acquisitions, including acquisitions to expand our RNG production capacity; pursuing market expansion as opportunities arise, including geographically and to new customer markets; and to fund other activities or pursuits and for other general corporate purposes.

As of June 30, 2026, we anticipate spending of approximately $148.4 million in capital expenditures for the next 12 months for RNG projects, fuel stations and our share of contributions in our equity method investment projects. This includes projects which have not been fully committed. These expenditures do not include any expected contributions from our joint venture partners and primarily relate to our development and construction of new renewable energy facilities and the purchase of equipment used in our Fueling Station services and Renewable Power operations.

In addition to the above, we also have lease commitments on our vehicle fleets and office leases and quarterly amortization payment obligations under various debt facilities. Please see Note 3. Loans and Note 12. Commitments and Contingencies to our condensed consolidated financial statements for additional information.

We plan to fund these expenditures primarily through cash on hand, cash generated from operations and availability under existing debt facilities.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

As a smaller reporting company, we are not required to provide the information required by this Item.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Our management, with the participation of our Co-Chief Executive Officers and our Chief Financial Officer (our co-principal executive officers and principal financial officer, respectively), evaluated, as of the end of the period covered by this Quarterly Report on Form 10-Q, the effectiveness of our disclosure controls and procedures as defined in Rules 13a-15(e) or 15d-15(e) under the Exchange Act. The term “disclosure controls and procedures,” as defined in the Exchange Act, means controls and other procedures of a company that are designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized, and reported, within the time periods specified in the Securities and Exchange Commission's rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the Exchange Act is accumulated and communicated to the company's management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosures. Management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving their objectives, and management necessarily applies its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

Based on that evaluation of our disclosure controls and procedures as required by Rules 13a-15(b) or 15d-15(b) under the Exchange Act, as of June 30, 2026, our Co-Chief Executive Officers and Chief Financial Officer concluded that, as of such date, our disclosure controls and procedures were effective for the period covered by this report.

Changes in Internal Controls over Financial Reporting

No change in our internal control over financial reporting (as defined in Rules 13a-15(f) or 15d-15(f) under the Exchange Act) was identified in the evaluation required by Rule 13a-15(d) or 15d-15(d) under the Exchange Act during the quarter ended June 30, 2026 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Part II - Other Information

Item 1. Legal Proceedings

From time to time, we are involved in various legal proceedings, lawsuits and claims incidental to the conduct of our business, some of which may be material. Our businesses are also subject to extensive regulation, which may result in regulatory proceedings against us. We do not believe that the outcome of any of our current legal proceedings will have a material adverse impact on our business, financial condition and results of operations. For more information about our pending legal proceedings, please refer to Note 12. Commitments and Contingencies.

Item 1A. Risk Factors

There have been no material changes from the “Risk Factors” previously disclosed in our Annual Report on Form 10-K for the year ended December 31, 2025, filed with the SEC on March 16, 2026. The risks described in such reports are not the only risks we face. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

Rule 10b5-1 Trading Plans

During the fiscal quarter ended June 30, 2026, none of the Company’s directors or executive officers adopted or terminated any contract, instruction or written plan for the purchase or sale of Company securities that was intended to satisfy the affirmative defense conditions of Rule 10b5-1(c) or any “non-Rule 10b5-1 trading arrangement.”

Item 6. Exhibits


Exhibit Number						Description
3.1						Restated Certificate of Incorporation of OPAL Fuels Inc. (incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K/A filed by the Company on August 10, 2022).
3.2						Bylaws of OPAL Fuels Inc. (incorporated by reference to Exhibit 3.2 to the Current Report on Form 8-K filed by the Company on July 27, 2022).
3.3						Amended and Restated Certificate of Designations of Series A Preferred Units of OPAL Fuels LLC, dated March 6, 2026 (incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K filed by the Company on March 9, 2026).
3.4						Amended and Restated Certificate of Designations of Series A-1 Preferred Units of OPAL Fuels LLC, dated May 18, 2026 (incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K filed by the Company on May 20, 2026).
31.1						Certification of Co-Principal Executive Officer Pursuant to Rules 13a-14(a) and 15d-14(a) under the Securities Exchange Act of 1934, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2						Certification of Co-Principal Executive Officer Pursuant to Rules 13a-14(a) and 15d-14(a) under the Securities Exchange Act of 1934, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.3						Certification of Principal Financial Officer Pursuant to Rules 13a-14(a) and 15d-14(a) under the Securities Exchange Act of 1934, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1*						Certification of Co-Principal Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2*						Certification of Co-Principal Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.3*						Certification of Principal Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS						Inline XBRL Instance Document
101.SCH						Inline XBRL Taxonomy Extension Schema Document
101.CAL						Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF						Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB						Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE						Inline XBRL Taxonomy Extension Presentation Linkbase Document
104						Cover Page Interactive Data File (embedded within the Inline XBRL document).


*						This certification is deemed not filed for purposes of Section 18 of the Exchange Act, or otherwise subject to the liability of that section, nor shall it be deemed incorporated by reference into any filing under the Securities Act or the Exchange Act.

SIGNATURES

Pursuant to the requirements 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.

Date: August 10, 2026