OPAL 10-Q Quarterly Report June 30, 2025

OPAL FUELS INC.

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wdq-20250630

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, 2025


☐			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						98-1578357
(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 7, 2025 , a total of 28,996,177 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,” “estimates,” “expects,” “forecasts,” “future,” “goal,” “intends,” “may,” “objective,” “outlook,” “plans,” “projected,” “propose,” “seeks,” “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 landfill gas ("LFG") and livestock waste projects that generate electricity and renewable natural gas (“RNG”), compressed natural gas (“CNG”) 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), low carbon fuel standard ("LCFS") credits and other incentives;

▪ the ability to identify, acquire, develop and operate renewable projects and fueling stations ("Fueling Stations");

▪ 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 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 Form 10-Q and in our Annual Report on Form 10-K, which was filed with the SEC on March 17, 2025 (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 3 0 , 2025 and December 31, 202 4	1
	Condensed Consolidated Statements of Operations for the three and six months e nded June 3 0 , 2025 and 202 4	3
	Condensed Consolidated Statements of Comprehensive Income / ( L oss) for the three and six months ended June 3 0 , 2025 and 202 4	5
	Condensed Consolidated Statements of Changes In Redeemable Non-Controlling Interest, Redeemable Preferred Non-Controlling Interest And Stockholders' ( Deficit ) Equity for the three and six months ended June 3 0 , 2025 and 202 4	5
	Condensed Consolidated Statements of Cash Flows for the six months ended June 3 0 , 2025 and 202 4	7
	Notes To Condensed Consolidated Financial Statements	9
ITEM 2.	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	36
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	50
ITEM 4.	CONTROLS AND PROCEDURES	50

PART II. OTHER INFORMATION
ITEM 1.	LEGAL PROCEEDINGS	51
ITEM 1A.	RISK FACTORS	52
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	53
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	53
ITEM 4.	MINE SAFETY DISCLOSURES	53
ITEM 5.	OTHER INFORMATION	54
ITEM 6.	EXHIBITS	54
SIGNATURES		56

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 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.

“Biogas Conversion Projects” refers to projects derived from the recovery and processing of biogas from landfills and other non-fossil fuel sources, such as livestock and dairy farms, for beneficial use as a replacement to fossil fuels.

“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.

“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.

“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 to 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.

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

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

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

“Btu” refers to British thermal units.

“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.

“GHG” refers to greenhouse gases.

"ISCC Carbon Credits" refers to Environmental Attributes associated with renewable biomethane.

“ISOs” refers to independent system operators.

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

“LFG” refers to landfill gas.

"MMBtus" refers to million British thermal units.

"PTC" refers to the Production Tax Credit.

“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.

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)

(Unaudited)


	June 30, 2025		December 31, 2024

Assets
Current assets:
Cash and cash equivalents (includes $ 373 and $ 358 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	$	29,269	$	24,310
Accounts receivable, net of allowance for credit losses of $ 2,454 and $ — , respectively (includes $ 25 and $ 435 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	29,085		32,013
Accounts receivable, related party	25,496		14,522
Restricted cash - current (includes $ 979 and $ 972 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	979		972

Fuel tax credits receivable	3,264		5,639
Contract assets	10,556		11,075
Parts inventory	13,004		10,294
Prepaid expense and other current assets (includes $ 62 and $ 144 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	11,833		18,363
Total current assets	123,486		117,188
Property, plant, and equipment, net (includes $ 31,303 and $ 25,428 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	477,063		458,258
Investment in other entities	224,577		223,594
Other long-term assets	22,546		23,483
Restricted cash - non-current (includes $ 2,528 and $ 2,315 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	3,257		3,946
Goodwill	54,608		54,608
Total assets	905,537		881,077
Liabilities and Stockholders' Deficit
Current liabilities:
Accounts payable (includes $ 36 and $ 22 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	19,589		16,419
Accounts payable, related party (includes $ — and $ 426 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	8,288		7,932
Fuel tax credits payable	3,471		4,422
Accrued payroll (includes $ 27 and $ 45 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	7,663		9,580
Accrued capital expenses	24,859		23,238
Accrued environmental credit rebates	4,705		5,391
Accrued expenses and other current liabilities (includes $ 1,008 and $ 974 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	12,969		14,717
Contract liabilities	8,631		9,276
OPAL Term Loan - current portion	6,233		10,865
Sunoma Loan - current portion (includes $ 1,825 and $ 1,756 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	1,825		1,756
Total current liabilities	98,233		103,596
OPAL Term Loan, net of debt issuance costs	295,753		266,630
Sunoma Loan, net of debt issuance costs (includes $ 17,515 and $ 18,373 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	17,515		18,373
Operating lease liabilities - non-current portion	12,007		12,155
Other long-term liabilities (includes $ 1,357 and $ 2,495 at June 30, 2025 and December 31, 2024, respectively, related to consolidated VIEs)	8,783		15,291


Total liabilities	432,291		416,045
Redeemable preferred non-controlling interests	130,000		130,000
Redeemable non-controlling interests	365,548		482,863
Stockholders' deficit:
Class A common stock, $ 0.0001 par value, 340,000,000 shares authorized as of June 30, 2025; shares issued: 30,631,960 and 30,065,260 at June 30, 2025 and December 31, 2024, respectively; shares outstanding: 28,996,177 and 28,429,477 at June 30, 2025 and December 31, 2024, respectively	3		3
Class B common stock, $ 0.0001 par value, 160,000,000 shares authorized as of June 30, 2025; 121,500,000 issued and outstanding as of June 30, 2025 and 71,500,000 issued and outstanding as of December 31, 2024	12		7
Class C common stock, $ 0.0001 par value, 160,000,000 shares authorized as of June 30, 2025; none issued and outstanding as of June 30, 2025 and December 31, 2024	—		—
Class D common stock, $ 0.0001 par value, 160,000,000 shares authorized as of June 30, 2025; 22,899,037 shares issued and outstanding at June 30, 2025 and 72,899,037 issued and outstanding as of December 31, 2024	2		7
Additional paid-in capital	—		—
Accumulated deficit	( 13,442 )		( 137,004 )
Accumulated other comprehensive income	2		152
Class A common stock in treasury, at cost; 1,635,783 at June 30, 2025 and December 31, 2024	( 11,614 )		( 11,614 )
Total Stockholders' deficit attributable to the Company	( 25,037 )		( 148,449 )
Non-redeemable non-controlling interests	2,735		618
Total Stockholders' deficit	( 22,302 )		( 147,831 )
Total liabilities, Redeemable preferred non-controlling interests, Redeemable non-controlling interests and Stockholders' deficit	$	905,537	$	881,077

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,
	2025		2024		2025		2024
Revenues:
RNG Fuel (includes revenues from related parties of $ 17,878 and $ 15,881 for the three months ended June 30, 2025 and 2024, respectively; $ 37,979 and $ 31,376 for the six months ended June 30, 2025 and 2024, respectively)	$	25,130	$	19,445	$	52,729	$	37,172
Fuel Station Services (includes revenues from related parties of $ 12,826 and $ 11,628 for the three months ended June 30, 2025 and 2024, respectively; $ 29,429 and $ 21,708 for the six months ended June 30, 2025 and 2024, respectively)	47,026		39,257		97,704		76,399
Renewable Power (includes revenues from related parties of $ 1,488 and $ 1,804 for the three months ended June 30, 2025 and 2024, respectively; $ 2,654 and $ 3,330 for the six months ended June 30, 2025 and 2024, respectively)	8,300		12,248		15,430		22,331
Total revenues	80,456		70,950		165,863		135,902
Operating expenses:
Cost of sales - RNG Fuel	11,414		8,321		23,567		16,659
Cost of sales - Fuel Station Services	38,731		30,938		78,453		61,273
Cost of sales - Renewable Power	6,899		8,899		13,661		18,157
Project development and startup costs	3,477		2,935		9,558		3,720
Selling, general, and administrative	17,460		13,699		33,427		26,860
Depreciation, amortization, and accretion	5,264		4,269		11,206		7,980
Income from equity method investments	( 1,962 )		( 3,800 )		( 1,240 )		( 8,006 )
Total expenses	81,283		65,261		168,632		126,643
Operating (loss) income	( 827 )		5,689		( 2,769 )		9,259
Other (expense) income:
Interest and financing expense, net	( 6,367 )		( 4,989 )		( 12,432 )		( 8,950 )
Change in fair value of derivative instruments, net	—		776		281		1,179
Other income	1,067		432		2,040		1,097
Total other expenses	( 5,300 )		( 3,781 )		( 10,111 )		( 6,674 )
(Loss) income before provision for income taxes	( 6,127 )		1,908		( 12,880 )		2,585
Income tax benefit	13,686		—		21,723		—
Net income	7,559		1,908		8,843		2,585
Net income (loss) attributable to redeemable non-controlling interests	3,982		( 753 )		2,808		( 2,380 )
Net income attributable to non-redeemable non-controlling interests	160		196		236		198
Dividends on redeemable preferred non-controlling interests (1)	2,617		2,618		5,234		5,236
Net income (loss) attributable to Class A common stockholders	$	800	$	( 153 )	$	565	$	( 469 )
Weighted average shares outstanding of Class A common stock:
Basic	28,265,710		27,674,567		27,995,258		27,523,150
Diluted	29,229,245		27,674,567		28,688,505		27,523,150
Per share amounts:
Basic	$	0.03	$	( 0.01 )	$	0.02	$	( 0.02 )
Diluted	$	0.03	$	( 0.01 )	$	0.02	$	( 0.02 )

(1) Dividends on redeemable preferred non-controlling interests is allocated between redeemable non-controlling interests and Class A common stockholders based on their weighted average percentage of ownership. Please see Note. 8 Redeemable non-controlling interests, redeemable preferred non-controlling interests and Stockholders' Deficit for additional information.

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

OPAL FUELS INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In thousands of U.S. dollars)

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Net income	$	7,559	$	1,908	$	8,843	$	2,585
Other comprehensive income:
Effective portion of the cash flow hedge attributable to equity method investments	( 89 )		165		( 253 )		515
Net unrealized loss on cash flow hedges	( 247 )		—		( 648 )		—
Total comprehensive income	7,223		2,073		7,942		3,100
Net income attributable to redeemable non-controlling interests (1)	6,162		1,430		7,168		1,995
Other comprehensive (loss) income attributable to redeemable non-controlling interests	( 282 )		137		( 751 )		430
Comprehensive income attributable to non-redeemable non-controlling interests	160		196		236		198
Dividends on redeemable preferred non-controlling interests	438		435		875		861
Comprehensive income (loss) attributable to Class A common stockholders	$	745	$	( 125 )	$	414	$	( 384 )

(1) Includes $ 2,180 and $ 2,183 of dividends attributable to redeemable non-controlling interests for the three months ended June 30, 2025 and 2024, respectively; Includes $ 4,360 and $ 4,375 of dividends attributable to redeemable non-controlling interests for the six months ended June 30, 2025 and 2024, respectively.

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' (DEFICIT) EQUITY

(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		(Accumulated deficit) Retained Earnings		Accumulated other comprehensive income		Non-redeemable non-controlling interests		Shares	Amount		Total Stockholders' (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 (1)	542,404	—		—	—		—	—		( 382 )		—		—		—		—	—		( 382 )		—		—


Stock-based compensation	—	—		—	—		—	—		293		—		—		—		—	—		293		—		1,458
Distributions to non-redeemable non-controlling interests	—	—		—	—		—	—		—		—		—		( 60 )		—	—		( 60 )		—		—
Dividends on redeemable preferred non-controlling interests	—	—		—	—		—	—				( 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 (1)	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 (2)	7,192	—		—	—		—	—		( 5 )		—		—		—		—	—		( 5 )		—		—
Stock-based compensation	—	—		—	—		—	—		369		—		—		—		—	—		369		—		1,835
Distributions to non-redeemable non-controlling interests	—	—		—	—		—	—		—		—		—		( 50 )		—	—		( 50 )		—		—
Dividends on redeemable preferred non-controlling interests	—	—		—	—		—	—		—		( 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

(1) During the six months ended June 30, 2025, the Company issued shares of Class A common stock under the Company's ATM program. Please see Note 8. Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' (Deficit) Equity for additional information.

(2) Represents the equity awards vested net of shares of Class A common stock withheld for taxes. Please see Note 11. Stock-based Compensation for additional information.


	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		Accumulated deficit		Accumulated other comprehensive (loss) income		Non-redeemable non-controlling interests		Shares	Amount		Total Stockholders' Deficit		Redeemable Preferred non-controlling interests		Redeemable non-controlling interests
December 31, 2023	29,701,146	$	3	—	$	—	144,399,037	$	14	$	—	$	( 467,195 )	$	( 15 )	$	955	( 1,635,783 )	$	( 11,614 )	$	( 477,852 )	$	132,617	$	802,720
Net income	—	—		—	—		—	—		—		110		—		2		—	—		112		—		565
Other comprehensive income	—	—		—	—		—	—		—		—		57		—		—	—		57		—		293

Issuance of Class A common stock under the ATM program (1)	14,005	—		—	—		—	—		97		—		—		—		—	—		97		—		—
Share conversion	—	—		71,500,000	7		( 71,500,000 )	( 7 )		—		—		—		—		—	—		—		—		—
Issuance of Class A common stock for vesting of equity awards (2)	307,137	—		—	—		—	—		( 627 )		—		—		—		—	—		( 627 )		—		—


Stock-based compensation	—	—		—	—		—	—		165		—		—		—		—	—		165		—		848
Distributions to non-redeemable non-controlling interests	—	—		—	—		—	—		—		—		—		( 233 )		—	—		( 233 )		—		—
Dividends on redeemable preferred non-controlling interests	—	—		—	—		—	—		—		( 426 )		—		—		—	—		( 426 )		2,618		( 2,192 )
Change in redemption value of Redeemable non-controlling interests	—	—		—	—		—	—		365		96,679		—		—		—	—		97,044		—		( 97,044 )
Payment of preferred dividend	—	—		—	—		—	—		—		—		—		—		—	—		—		( 5,235 )		—
March 31, 2024	30,022,288	$	3	71,500,000	$	7	72,899,037	$	7	$	—	$	( 370,832 )	$	42	$	724	( 1,635,783 )	$	( 11,614 )	$	( 381,663 )	$	130,000	$	705,190
Net income	—	—		—	—		—	—		—		282		—		196		—	—		478		—		1,430
Other comprehensive income	—	—		—	—		—	—		—		—		28		—		—	—		28		—		137
Issuance of Class A common stock under the ATM program (1)	22,348	—		—	—		—	—		73		—		—		—		—	—		73		—		—
Issuance of Class A common stock for vesting of equity awards (2)	13,933	—		—	—		—	—		—		—		—		—		—	—		—		—		—
Stock-based compensation	—	—		—	—		—	—		304		—		—		—		—	—		304				1,538
Distributions to non-redeemable non-controlling interests	—	—		—	—		—	—		62		—		—		( 403 )		—	—		( 341 )		—		—
Dividends on redeemable preferred non-controlling interests	—	—		—	—		—	—		—		( 435 )		—		—		—	—		( 435 )		2,618		( 2,183 )
Change in redemption value of Redeemable non-controlling interests	—	—		—	—		—	—		( 439 )		109,482		—		—		—	—		109,043		—		( 109,043 )
Payment of preferred dividend	—	—		—	—		—	—		—		—		—		—		—	—		—		( 2,618 )		—
June 30, 2024	30,058,569	$	3	71,500,000	$	7	72,899,037	$	7	$	—	$	( 261,503 )	$	70	$	517	( 1,635,783 )	$	( 11,614 )	$	( 272,513 )	$	130,000	$	597,069

(1) During the six months ended June 30, 2024, the Company issued shares of Class A common stock under the Company's ATM program. Please see Note 8. Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' (Deficit) Equity for additional information.

(2) Represents the equity awards vested net of shares of Class A common stock withheld for taxes.

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,
	2025		2024
Cash flows from operating activities:
Net income	$	8,843	$	2,585
Adjustments to reconcile net income to net cash provided by operating activities:
Income from equity method investments	( 1,240 )		( 8,006 )
Distributions from equity method investments	2,620		8,669

Provision for bad debts	2,454		—
Gain on lease termination	( 600 )		—
Reduction of carrying amount of operating lease right-of-use assets	359		334
Write-offs of capitalized costs	306		—
Depreciation and amortization	10,986		7,706
Accretion expense related to asset retirement obligation	220		274
Amortization of deferred financing costs	802		1,119
Stock-based compensation	3,956		2,855
Paid-in-kind interest income	( 125 )		( 136 )
Change in fair value of commodity swaps	( 595 )		324
Unrealized gain on note receivable	( 815 )		—
Unrealized gain on derivative financial instruments	( 281 )		( 1,179 )
Changes in operating assets and liabilities
Accounts receivable	474		3,403
Accounts receivable, related party	( 10,974 )		3,958
Fuel tax credits receivable	2,375		( 54 )
Contract assets	519		( 5,986 )
Parts inventory	( 2,710 )		( 429 )
Prepaid expense and other current and long-term assets	7,788		( 2,477 )
Accounts payable	3,170		( 802 )
Accounts payable, related party	356		1,145
Fuel tax credits payable	( 951 )		( 609 )
Accrued payroll	( 1,917 )		( 1,650 )

Accrued expenses and other current and non-current liabilities	( 2,213 )		3,560
Operating lease liabilities - current and non-current	( 357 )		( 301 )
Contract liabilities	( 645 )		( 52 )
Net cash provided by operating activities	21,805		14,251
Cash flows from investing activities:
Purchase of property, plant, and equipment	( 33,409 )		( 49,742 )
Proceeds from sale of short-term investments	—		1,290
Distributions received from equity method investment	9,100		2,922
Cash paid to equity method investments	( 11,717 )		( 8,550 )
Net cash used in investing activities	( 36,026 )		( 54,080 )
Cash flows from financing activities:
Proceeds from OPAL Term Loan	40,000		25,000

Cash paid for taxes related to net share settlement of equity awards	( 387 )		( 627 )
Financing costs paid to other third parties	( 1,250 )		( 253 )
Repayment of OPAL Revolving Loan	( 15,000 )		—
Repayment of Sunoma Loan	( 863 )		( 783 )
Repayment of principal portion of finance lease liabilities	( 707 )		( 44 )
Payment of preferred dividends	( 5,234 )		( 7,853 )


Distribution to non-redeemable non-controlling interest	( 110 )		( 574 )
Proceeds from issuance of shares of Class A common stock under the ATM program, net	58		170


Capital contribution from non-redeemable non-controlling interests	1,991		—

Net cash provided by financing activities	18,498		15,036
Net increase (decrease) in cash, restricted cash, and cash equivalents	4,277		( 24,793 )
Cash, restricted cash, and cash equivalents, beginning of period	29,228		47,242
Cash, restricted cash, and cash equivalents, end of period	$	33,505	$	22,449
Supplemental disclosure of cash flow information
Interest paid, net of $ 1,241 and $ 2,074 capitalized, respectively	$	13,304	$	7,185
Tax benefit received	$	21,723	$	—
Noncash investing and financing activities:
Accrual for asset retirement obligation included in Property, plant and equipment	$	—	$	591
Right-of-use assets arising from lease modifications	$	—	$	1,218

Accrual for purchase of Property, plant and equipment included in Accounts payable and Accrued capital expenses	$	24,859	$	18,324

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

1. Summary of Significant Accounting Policies

Basis of Presentation and Principles of Consolidation

The unaudited condensed consolidated financial statements include the accounts of OPAL Fuels, Inc. and its subsidiaries (the “Company”, “OPAL Fuels”, “we,” “us” or “our”) and reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair statement of the results of operations for the interim period. In addition, we have consolidated the financial results of jointly owned affiliated companies in which our principal stockholder or other entities have a noncontrolling interest. All intercompany transactions and balances have been eliminated in consolidation. The non-controlling interest attributable to the Company's variable interest entities ("VIE") are presented as a separate component from the Stockholders' (deficit) equity in the condensed consolidated balance sheets and as a non-redeemable non-controlling interest in the condensed consolidated statements of changes in redeemable non-controlling interests, redeemable preferred non-controlling interests and stockholders' equity (deficit).

As of June 30, 2025 , the Company held equity interests in twelve VIEs — Pine Bend RNG LLC ("Pine Bend"), Noble Road RNG LLC ("Noble Road"), Paragon RNG LLC ("Paragon"), Emerald RNG LLC ("Emerald") - Paragon project, Sapphire RNG LLC ("Sapphire") - Paragon project, Land2Gas LLC ("Land2Gas"), Atlantic RNG LLC ("Atlantic") - Land2Gas project , Burlington RNG LLC ("Burlington") - Land2Gas project, GREP BTB Holdings LLC ("GREP"), Sunoma Holdings, LLC (“Sunoma”), Central Valley LLC (“Central Valley”), and CMS RNG LLC ("CMS"). Pine Bend, Noble Road GREP, Paragon projects, Land2Gas projects were presented as equity method investments and the remaining three VIEs — Sunoma, Central Valley, and CMS are consolidated by the Company.

On May 9, 2025, the Company acquired a variable interest in CMS, a joint venture formed with a third party to develop, construct, own, and operate a renewable natural gas facility. The Company holds a 70 % membership interest in CMS RNG, and the remaining 30 % is held by the third-party partner.

Based on an evaluation under ASC 810, Consolidation ( "ASC 810"), management determined that CMS RNG is a VIE and that the Company is the primary beneficiary. This conclusion is based on the Company’s power to direct the activities that most significantly impact CMS RNG’s economic performance and its exposure to the entity’s residual returns. As a result, CMS RNG has been consolidated in the Company’s financial statements beginning in the second quarter of 2025.

At the time of formation, the Company and the third-party partner made net capital co ntributions of $ 4,646 an d $ 1,998 , respectively. A noncontrolling interest ("NCI") of $ 1,998 was recognized for the portion of CMS RNG not owned by the Company.

The Company will reassess its primary beneficiary conclusion on an ongoing basis, including upon execution of additional agreements and commencement of commercial operations.

The condensed consolidated balance sheets summarize the major consolidated balance sheet items for consolidated VIEs as of June 30, 2025 and December 31, 2024. The information is presented on an aggregate basis based on similar risk and reward characteristics and the nature of our involvement with the VIEs, such as:

• All of the VIEs are RNG facilities and they are reported under the RNG Fuel Supply segment;

• The nature of our interest in these entities is primarily equity based and therefore carry similar risk and reward characteristics.

The 2024 year-end consolidated balance sheet data was derived from audited financial statements, but does not include all disclosures required by accounting principles generally accepted in the United States of America ("U.S. GAAP"). The interim financial information and notes thereto should be read in conjunction with the Company's latest Annual Report on Form 10-K for the fiscal year ended December 31, 2024 (the "Annual Report") as the interim disclosures generally do not repeat those in the annual financial statements and are condensed in accordance with the instructions to Form 10-Q and Article 10 of Regulation S-X. The results of operations for the three and six months ended June 30, 2025, are not necessarily indicative of results to be expected for the entire fiscal year.

The Company is organized into three operating segments based on the characteristics and the nature of products and services. The three operating segments are RNG Fuel, Fuel Station Services and Renewable Power.

All amounts in these footnotes are presented in thousands of dollars except share and per share data.

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. The significant estimates and assumptions of the Company include the residual value of the useful lives of our property, plant and equipment, the impairment of long-lived assets, the fair value of stock-based compensation, asset retirement obligations, percentage completion for revenue recognition, incremental borrowing rate for calculating the right-of-use lease assets and lease liabilities, the impairment assessment of goodwill and the fair value of derivative instruments. Actual results could differ from those estimates.

The results of operations for the interim periods presented are not necessarily indicative of the results that may be expected for the entire year.

The Company provides all third-party construction contracts with a warranty, typically for a period of one year after substantial completion of the construction project. These warranties are accounted for under ASC 460, Guarantees ("ASC 460"), and not as a separate performance obligation. Generally, the company estimates warranty costs based on historical claims experience, and other factors. Actual warranty claims may differ from the estimates, and adjustments to the liability are made as necessary. The Company accrued $ 219 and $ 171 of warranty reserves under accrued expenses and other current liabilities as of June 30, 2025, and December 31, 2024, respectively.

Related Party Revenues

The Company revised its disclosure of Fuel Station Services revenues from related parties included parenthetically on the face of the condensed consolidated statements of operations to include amounts that were previously excluded. The amounts are immaterial and the revision had no impact on previously reported net income, cash flows, or financial position.

Accounting Pronouncements Adopted

In August 2023, the FASB issued Accounting Standards Update No. 2023-05, Business Combinations- Joint Venture Formations (Subtopic 805-60) ("ASU 2023-05"). The update requires all joint ventures formed after January 1, 2025, upon formation, to apply a new basis of accounting and initially measure its assets and liabilities at fair value. ASU 2023-05 is effective prospectively for joint ventures with a formation date on or after January 1, 2025. During the six months ended June 2025, the Company formed a joint venture that was excluded from this guidance due to the scope exception applicable to combinations between entities, businesses, or nonprofit activities under common control. The adoption did not have a material effect on the Company’s financial position, results of operations, cash flows or disclosures.

Accounting Pronouncements Not Yet Adopted

In December 2023, the FASB issued ASU 2023-09, Income Taxes (Topic 740), Improvement to Income Tax Disclosures . The amendments further enhance income tax disclosures, primarily through standardization and disaggregation of rate reconciliation categories and income taxes paid by jurisdiction. The amendments require disclosure of specific categories in the rate reconciliation and provide additional information for reconciling items that meet a quantitative threshold and further disaggregation of income taxes paid for individually significant jurisdictions. The ASU is effective for fiscal years beginning after December 15, 2024, with early adoption permitted. The Company is currently evaluating the impact that this guidance will have on the disclosures within our condensed consolidated financial statements.

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 line items. The ASU is effective for fiscal years beginning after December 15, 2026, and is required 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.

Earnout Liabilities

In connection with the Business Combination completed in July 2022 and pursuant to a sponsor letter agreement, ArcLight CTC Holdings II, L.P. agreed to subject 10 % of its Class A common stock (received as a result of the conversion of its ArcLight Class B ordinary shares immediately prior to the closing) to vesting and forfeiture conditions relating to VWAP targets for the Company's Class A common stock sustained over a period of 60 months following the closing. As of June 30, 2025 and December 31, 2024, the number of shares subject to forfeiture was 716,650 (the "Sponsor Earnout Awards").

For the three and six months ended June 30, 2025 the Company recorded a gain from the Sponsor Earnout Awards of $ — and $ 281 , respectively, in its condensed consolidated statements of operations. For the three and six months ended June 30, 2024, the Company recorded a gain of $ 776 and $ 1,179 , respectively, in its condensed consolidated statements of operations. As of June 30, 2025 and December 31, 2024, the Company recorded a Sponsor Earnout liability of $ 23 and $ 304 , respectively, as part of other long-term liabilities on its condensed consolidated balance sheets.

Redeemable non-controlling interests

Redeemable non-controlling interests represent the portion of the Company's consolidated subsidiary OPAL Fuels LLC, that the Company does not own. The Redeemable non-controlling interest represents 144,399,037 Class B Units issued by OPAL Fuels to the prior investors. The Company allocates net income or loss attributable to Redeemable non-controlling interest based on weighted average ownership interest during the period. The net income or loss attributable to Redeemable non-controlling interests is reflected in the condensed consolidated statements of operations.

At each balance sheet date, the mezzanine equity classified Redeemable non-controlling interests is adjusted up to their maximum redemption value if necessary, with an offset in Stockholders' equity (deficit). As of June 30, 2025, the maximum redemption value was $ 365,548 .

Parts Inventory

Parts inventory, also referred to as supplies inventory, consists of shop spare parts inventory and construction site parts inventory. The substantial amount of inventory is identified, tracked and treated as finished goods.

Revenues

Disaggregation of Revenue

The following table shows the disaggregation of revenue according to product line:


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Electricity sales	$	5,889	$	6,833	$	11,893	$	12,652
Third party construction	9,184		8,705		17,175		19,495
Service	6,311		5,102		12,920		10,437
Brown gas sales	10,615		5,768		16,979		11,370
Environmental credits (1)	44,687		42,370		99,864		78,047
Parts sales	336		751		880		1,148
Other (2)	424		276		701		617
Total revenue from contracts with customers	77,446		69,805		160,412		133,766
Lease revenue (3)	3,010		1,145		5,451		2,136
Total revenue	$	80,456	$	70,950	$	165,863	$	135,902

(1) Includes revenues of $ 0 and $ 4,671 respectively, for the three months ended June 30, 2025 and 2024, from customers domiciled outside of United States. Includes revenues of $ 0 and $ 8,288 respectively, for the six months ended June 30, 2025 and 2024, from customers domiciled outside of United States.

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

(3) Lease revenue relates to approximately thirty-nine fuel purchasing agreements out of which we have two of our RNG Fuel stations with minimum take or pay provisions and revenue from power purchase agreements at two of our Renewable Power facilities where we determined that we transferred the right to control the use of the power plant to the purchaser.

For the three and six months ended June 30, 2025 and 2024, the third party construction revenue was recognized over time, and the remainder was for products and services transferred at a point in time.

Contract Balances

The following table provides information about receivables, contract assets, and contract liabilities from contracts with customers:


	June 30, 2025		December 31, 2024
Accounts receivable, net	$	29,085	$	32,013
Contract assets:
Cost and estimated earnings in excess of billings	$	9,202	8,547
Accounts receivable retainage, net	1,354		2,528
Contract assets total	$	10,556	$	11,075
Contract liabilities:
Billings in excess of costs and estimated earnings	$	8,631	9,276
Contract liabilities total	$	8,631	$	9,276

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. During the six months ended June 30, 2024, the Company recognized revenue of $ 3,746 that was included in "Contract liabilities" at December 31, 2023.

Environmental credits held for sale

For the three months ended June 30, 2025 and 2024, the Company recorded $ 4,693 and $ 3,694 as part of Cost of sales - Fuel Station Services in its 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, 2025 and 2024, the Company recorded $ 10,540 and $ 6,850 as part of Cost of sales - Fuel Station Services in its condensed consolidated statements of operations to adjust environmental credits held for sale to lower of cost and net realizable value.

Fuel Station Services Construction Backlog

The Company's remaining performance obligations ("backlog") represent the unrecognized revenue value of its contract commitments. The Company's backlog may significantly vary each reporting period based on the timing of major new contract commitments. At June 30, 2025, the Company had a backlog of $ 55,505 .

Significant Customers, Vendors and Concentration of Credit Risk

For the three an d six months ended June 30, 2025, one customer accounted for 37 % and 39 %, respectively, of the revenue. For the three and six months ended June 30, 2024, two customers accounted for 53 % of the revenue. At June 30, 2025, two customers accounted for 61 % of accounts receivable. At December 31, 2024, two customers accounted for 50 % of accounts receivable.

As of June 30, 2025 , two vendors accounted for 54 % of the accounts payable. As of December 31, 2024, one vendor accounted for 17 % of the accounts payable.

Investment Tax Credits

In the first and second quarters of 2025, the Company sold to third-party purchasers certain transferable Investment Tax Credits (ITCs) that had been generated by the Company from its investments in the Renewable Natural Gas segment.

The Company elected to consider expected transfers of the credits in assessing their realizability as part of the valuation allowance analysis and recognize changes in the estimated proceeds as an adjustment to its valuation allowance. The Company accounted for the ITC sale in accordance with ASC 740, Income Taxes ("ASC 740"), by electing the flow-through method to recognize the ITC benefit when it arises.

During the three and six months ended June 30, 2025, the Company received net proceeds from the sale of tax credits totaling $ 13,686 and $ 21,723 , respectively. These amounts were received in cash and recorded as income tax benefit as of June 30, 2025. The cash flows related to the total income tax benefits are presented in the statement of cash flow in the ‘Net income’ line item within operating activities. Additionally, during the three and six months ended June 30, 2025, the Company incurred legal and insurance fees associated with the transactions totaling $ 1,775 and $ 2,637 , respectively. These amounts represent buyer’s expenses paid by the Company and are recorded as part of the income tax benefit. The transaction costs are deductible for income tax purposes.

2. Investment in Other Entities

The following table shows the movement in Investment in Other Entities:


	Pine Bend			Noble Road			GREP			Land2Gas			Paragon			Total
Percentage of ownership	50		%	50		%	20		%	50		%	50		%

Balance at December 31, 2024	$	19,536		$	21,097		$	1,760		$	16,384		$	164,817		$	223,594
Net income (loss) from equity method investment	677			2,315			( 380 )			( 608 )			2,656			4,660
Contribution by the Company	—			—			—			10,900			—			10,900
Distributions from return on investment in equity method investment (1)	( 599 )			( 2,021 )			—			—			—			( 2,620 )
Distributions from return of investment in equity method investment (2)	( 401 )			( 104 )			—			—			( 8,595 )			( 9,100 )
Other comprehensive loss	—			—			—			—			( 253 )			( 253 )
Amortization of basis difference (3)	( 78 )			( 295 )			—			—			( 3,047 )			( 3,420 )
Capitalized interest	—			—			—			816			—			816
Balance at June 30, 2025	$	19,135		$	20,992		$	1,380		$	27,492		$	155,578		$	224,577

(1) Recorded as part of cash flows from operating activities for the six months ended June 30, 2025.

(2) Recorded as part of cash flows from investing activities for the six months ended June 30, 2025.

(3) Reflected in income from equity method investments in the condensed consolidated statements of operations for the six months ended June 30, 2025.

The following table summarizes the statement of operations information for equity method investments and the Company's portion of net income from equity method investments:


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Revenue	$	31,757	$	25,567	$	54,274	$	50,974
Gross profit	11,567		9,919		14,382		21,013
Net income	8,549		8,693		6,283		19,397
Net income from equity method investments (1)	1,962		3,800		1,240		$	8,006

(1) Net income from equity method investments represents our portion of the net 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, 2025		December 31, 2024
Current assets	$	11,527	$	10,554
Non-current assets	133,426		121,934
Total assets	144,953		132,488
Current liabilities	14,277		15,993
Non-current liabilities	34,999		24,612
Total liabilities	$	49,276	$	40,605

3. Borrowings

The following table summarizes the borrowings under the various debt facilities as of June 30, 2025 and December 31, 2024:


	June 30, 2025		December 31, 2024
OPAL Term Loan and Revolving Loan	$	311,617	$	286,617
Less: unamortized debt issuance costs	( 9,631 )		( 9,122 )
Less: current portion	( 6,233 )		( 10,865 )
OPAL Term Loan and Revolving Loan, net of debt issuance costs	295,753		266,630
Sunoma Loan	19,983		20,846
Less: unamortized debt issuance costs	( 643 )		( 717 )
Less: current portion	( 1,825 )		( 1,756 )
Sunoma Loan, net of debt issuance costs	17,515		18,373
Non-current borrowings total	$	313,268	$	285,003

As of June 30, 2025, principal maturities of debt are expected as follows, excluding any undrawn debt facilities as of the date of the condensed consolidated balance sheets:


	OPAL Term Loan		Sunoma Loan		Total
Fiscal year:
Six months ending December 31, 2025	$	—	$	893	$	893
2026	12,465		1,898		14,363
2027	12,465		2,051		14,516
2028	286,687		2,213		288,900
2029	—		2,395		2,395
2030	—		2,589		2,589
Thereafter	—		7,944		7,944
	$	311,617	$	19,983	$	331,600

Amended OPAL Term Loan and Revolving Loan

On March 3, 2025, OPAL Fuels Intermediate HoldCo LLC, as the borrower (the “Borrower”), certain subsidiaries of the Borrower, as guarantors (the “Guarantors”), the lenders and issuers of letters of credit party thereto and Bank of America, N.A. as the administrative agent (the “Administrative Agent”) entered into that certain Amendment No. 1 to Credit and Guarantee Agreement (the “Credit Agreement Amendment”), with respect to that certain Credit and Guarantee Agreement (the “Credit Agreement”) dated September 1, 2023, by and among the Borrower, the Administrative Agent, the financial institutions from time to time parties thereto as lenders and as issuers of letters of credit, and the other agents and persons from time to time party thereto (as amended, restated, amended and restated, supplemented or otherwise modified and in effect from time to time).

The Credit Agreement Amendment makes certain changes to the applicability of certain financial covenants and modifies other covenants to clarify the use of loan proceeds. Additionally, the Credit Agreement Amendment permits the organizational restructuring of the Guarantors in a manner designed to facilitate the sale of federal investment tax credits and the ability to raise additional future capital.

The Credit Agreement Amendment also eases the conditions precedent to making new Projects eligible for borrowing under the Credit Agreement, extends the availability period for delay draw term loans under the Credit Agreement through March 5, 2026, and extends the commencement of repayment of such term loans until March 31, 2026. The Amendment was accounted for as a modification in the six month period ended June 30, 2025.

In connection with the Credit Agreement Amendment, the Borrower paid the Administrative Agent, for the account of each lender, a one-time nonrefundable fee of $ 1,250 . These costs have been recorded as a direct reduction against the debt and amortized over the life of the associated debt as a component of interest expense using the effective interest method.

During the six months ended June 30, 2025, the Company drew an additional $ 40,000 under its term loan and repaid $ 15,000 on its revolving loan. As of June 30, 2025, the Company utilized $ 14,517 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.

The Company has the ability, during the delayed draw availability period 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, 2025, the Company is in compliance with the financial covenants under the OPAL Term Loan. The amounts outstanding under the Credit Agreement are secured by the assets of the indirect subsidiaries of OPAL Intermediate Holdco.

Sunoma Loan

On August 27, 2020, Sunoma, an indirect wholly-owned subsidiary of the Company entered into a debt agreement (the "Sunoma Loan Agreement") with Live Oak Banking Company for an aggregate principal amount of $ 20,000 that was increased to $ 23,000 in 2022. As of June 30, 2025, Sunoma is in compliance with the financial covenants under the Sunoma Loan Agreement.

As of June 30, 2025 and December 31, 2024, the outstanding loan balance (current and non-current) excluding deferred financing costs was $ 19,983 and $ 20,846 , respectively. The Company also utilized $ 968 for the issuance of letters of credit to support the operations of the Borrower. The amounts outstanding under the Sunoma Loan are secured by the assets of Sunoma.

2025

For the three and six months ended June 30, 2025, the weighted average effective interest rate including amortization of debt issuance costs on OPAL Term Loan was 8.5 %. For the three and six months ended June 30, 2025, the interest rate on the Sunoma Loan was 8.7 %.

2024

For the three and six months ended June 30, 2024, the weighted average effective interest rate on OPAL Term Loan including amortization of debt issuance costs was 9.3 % and 7.9 %, respectively. For the three and six months ended June 30, 2024, the interest rate on the Sunoma loan was 8.5 % and 8.4 %, respectively.

The following table summarizes the Company's total interest expense for the three and six months ended June 30, 2025 and 2024:


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Senior secured credit facility	$	—	$	—	$	—	$	2
Sunoma Loan	390		440		808		901
OPAL Term Loan (1)	5,355		3,549		10,311		6,318
Equipment loan	—		5		—		10
Commitment fees and other finance fees	457		774		956		1,462
Amortization of deferred financing cost	364		564		802		1,119
Interest expense on finance leases	71		141		210		288
Interest income	( 270 )		( 484 )		( 655 )		( 1,150 )
Total interest and financing expense	$	6,367	$	4,989	$	12,432	$	8,950

(1) Excludes $ 717 and $ 640 of interest capitalized and recorded as part of Property, Plant and Equipment for the three months ended June 30, 2025 and 2024. Excludes $ 1,241 and $ 2,074 of interest capitalized and recorded as part of Property, Plant and Equipment for the six months ended June 30, 2025 and 2024 .

4. Leases

Lessor contracts

Fuel provider agreements

Fuel provider agreements ("FPAs") are for the sale of brown gas, service and maintenance of sites. The Company is contracted to design and build a Fueling Station on the customer's property in exchange for the Company providing CNG/RNG to the customer for a determined number of years. We have determined that the FPAs contain a lease component for the use of the Fueling Station in addition to the non-lease components related to providing CNG/RNG as well as providing all-inclusive maintenance and warranty services.

Included in Fuel Station Service revenues are $ 2,619 and $ 4,804 related to the lease portion of the FPAs for the three and six months ended June 30, 2025, respectively, and $ 935 and $ 1,707 related to the lease portion of the FPAs for the three and six months ended June 30, 2024, respectively. The Company allocated the contract consideration between the lease component and non-lease components on a relative standalone selling price basis.

Power purchase agreements

Power purchase agreements ("PPAs") are for the sale of electricity generated at our Renewable Power facilities. All of our Renewable Power facilities operate under fixed pricing or indexed pricing based on market prices. Two of our Renewable Power facilities transfer the right to control the use of the power plant to the purchaser and are therefore classified as operating leases.

Included in Renewable Power revenues are $ 391 and $ 647 related to the lease element of the PPAs for the three and six months ended June 30, 2025, respectively. It includes $ 210 and $ 429 related to the lease element of the PPAs for the three and six ended June 30, 2024, respectively.

Lessee contracts

During the six months ended June 30, 2025, the Company derecognized the right-of-use (ROU) asset and corresponding lease liability associated with a site lease following a formal release from all future lease obligations by the vendor under the current agreement. The ROU asset had a carrying value of approximately $ 5,397 at the time of termination. The derecognition resulted in $ 600 gain recognized in other income.

5. Derivative Financial Instruments and Fair Value Measurements

Interest rate swaps

The Company records the fair value of the interest rate swap as an asset or liability on its balance sheet. This instrument is classified as Level 2 in the fair value hierarchy. The effective portion of the swap is recorded in accumulated other comprehensive income. The Company expects to release $ 153 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:


	June 30, 2025		December 31, 2024		Location of Fair Value Recognized in Balance Sheet
Derivatives designated as cash flow hedges:
Short term portion of the interest rate swaps	$	153	$	238	Prepaid expenses and other current assets
Long term portion of the interest rate swaps	—		448		Other long-term assets
Long term portion of the interest rate swaps	( 115 )		—		Other long-term liabilities
	$	38	$	686

The effect of interest rate swaps on the condensed consolidated statement of operations were as follows:


	Three Months Ended June 30,				Six Months Ended June 30,				Location of (Loss) Gain Recognized in Operations from Derivatives
	2025		2024		2025		2024
Gain on net periodic settlements	$	72	$	—	$	145	$	—	Interest and financing expense, net
	$	72	$	—	$	145	$	—

Commodity swap contracts

In February 2025, the Company entered into a power purchase and sale agreement with NextEra Energy Marketing, LLC (together with its affiliates, "NextEra") for sale of electricity over the period from March through December 2025, with a fixed contract price. The forward contract is expected to be settled by physical delivery of electricity on a monthly basis. The Company elected the normal purchase normal sale exclusion and will not apply fair value accounting under ASC 815, Derivatives and Hedging, ("ASC 815").

Additionally, in the six months ended June 30, 2025, the Company entered into multiple ISDA agreements with JPMorgan Chase, Merrill Lynch, and Investec Bank for pay-variable, receive-fixed, cash-settled natural gas commodity swaps. The Company applied fair value accounting under ASC 815 for these transactions.

The following table summarizes the effect of commodity swaps accounted for as derivatives under ASC 815 on the condensed consolidated statements of operations for the three and six months ended June 30, 2025 and 2024:


Derivatives not designated as hedging instruments	Location of gain (loss) recognized	Three Months Ended June 30,				Six Months Ended June 30,
		2025		2024		2025		2024
Commodity swaps - realized gain (loss)	Revenues - Renewable Power	$	32	$	231	$	( 60 )	$	409
Commodity swaps - unrealized gain (loss)	Revenues - Renewable Power	1		( 228 )		( 12 )		( 324 )
Commodity swaps - realized gain	Revenues - RNG Fuel	804		—		871		—
Commodity swaps - unrealized gain	Revenues - RNG Fuel	1,935		—		607		—
Total realized and unrealized gain		$	2,772	$	3	$	1,406	$	85

The following table summarizes the derivative assets and liabilities related to commodity swaps as of June 30, 2025 and December 31, 2024:


	Fair Value				Location of Fair value recognized in Balance Sheet
	June 30, 2025		December 31, 2024
Derivatives not designated as hedging instruments
Current portion of unrealized gain on commodity swaps	$	702	$	—	Prepaid expense and other current assets
Current portion of unrealized loss on commodity swaps	( 179 )		( 9 )		Accrued expenses and other current liabilities
Non - current portion of unrealized loss on commodity swaps	—		( 63 )		Other long-term liabilities
Total commodity swaps - unrealized gain (loss)	$	523	$	( 72 )

Other derivative liabilities

On July 21, 2022, the Company recorded a derivative liability for the Sponsor Earnout Awards and the OPAL Earnout Awards. The OPAL Earnout Awards expired in December 2024. The change in fair value on Sponsor Earnout and OPAL Earnout Awards is recorded as change in fair value of derivative instruments, net in the condensed consolidated statement of operations for the three and six months ended June 30, 2025 and 2024.

The following table summarizes the effect of change in fair value of other derivative liabilities on the condensed consolidated statements of operations for the three and six months ended June 30, 2025 and 2024:


Derivative liability	Three Months Ended June 30,				Six Months Ended June 30,				Location of Gain Recognized in Operations from Derivatives
	2025		2024		2025		2024
Sponsor Earnout Awards gain	$	—	$	776	281		1,179
	$	—	$	776	$	281	$	1,179	Change in fair value of derivative instruments, net

Fair value measurements

The carrying amount of cash and cash equivalents, accounts receivable, net, and accounts payable and accrued expenses approximates fair value due to their short-term maturities.

The carrying value of the Company's long-term debt, which are considered Level 2 in the fair value hierarchy, of $ 321,326 and $ 297,624 as of June 30, 2025 and December 31, 2024, respectively, approximates its fair value because our interest rate is variable and reflects current market rates.

The Company accounts for asset retirement obligations by recording the fair value of a liability for an asset retirement obligation in the period in which it is incurred and when a reasonable estimate of fair value can be made. The Company estimated the fair value of its asset retirement obligations based on discount rates ranging from 5.8 % to 8.5 %.

The fair value of the Sponsor Earnout Awards as of June 30, 2025 was determined using a Black-Scholes valuation model with a distribution of potential outcomes on a daily basis over the 2.0 years remaining in the vesting window. Assumptions used in the valuation are as follows:

• Current stock price — The Company's closing stock price of $ 2.42 as of June 30, 2025;

• Expected volatility — 50 % based on historical and implied volatilities of selected industry peers deemed to be comparable to our business corresponding to the expected term of the awards;

• Risk-free interest rate — 3.7 % based on the U.S. Treasury yield curve in effect at the time of issuance for zero-coupon U.S. Treasury notes with maturities corresponding to the expected 2.0 year term of the earnout period;

• Dividend yield - zero .

Convertible note receivable

In July 2024, the Company purchased a convertible note pursuant to which the Company has the right to convert the note into shares of Class A common stock of the investee. As of June 30, 2025 , the fair value of the convertible note was equal to $ 1,575 and presented within prepaid expense and other current assets.

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

The Company's assets and liabilities that are measured at fair value on a recurring basis include the following as of June 30, 2025 and December 31, 2024, set forth by level, within the fair value hierarchy:


	Fair value as of June 30, 2025
	Level 1		Level 2		Level 3		Total
Liabilities:
Earnout liabilities	$	—	$	—	$	23	$	23
Interest rate swap contracts	—		115		—		115
Commodity swap contracts	—		179		—		179
Assets:
Cash and cash equivalents and restricted cash - current and non-current (1)	33,505		—		—		33,505
Interest rate swap contracts	—		153		—		153
Commodity swap contracts	—		702		—		702
Convertible note receivable	—		—		1,575		1,575


	Fair value as of December 31, 2024
	Level 1		Level 2		Level 3		Total
Liabilities:
Earnout liabilities	$	—	$	—	$	304	$	304
Commodity swap contracts	—		72		—		72
Assets:
Cash and cash equivalents and restricted cash - current and non-current (1)	29,228		—		—		29,228
Interest rate swap contracts	—		686		—		686
Convertible note receivable	—		—		760		760

(1) Includes balances in money market accounts of $ 22,934 and $ 19,786 , respectively as of June 30, 2025 and December 31, 2024.

6. Related Parties

Related parties are represented by Fortistar and other affiliates, subsidiaries, entities under common control with Fortistar or NextEra, and equity method investments.

Sale of redeemable preferred non-controlling interests to related parties

On November 29, 2021, NextEra subscribed for up to 1,000,000 Series A preferred units, which were issuable (in whole or in increments) at the Company’s discretion prior to June 30, 2022. During the year ended December 31, 2022, the Company had drawn $ 100,000 and issued 1,000,000 Series A preferred units. Please see Note 8. Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Equity (Deficit), for the dividends paid and additional information.

Purchase and sale agreement for environmental attributes

In January 2025, the EPA implemented a new framework in which (1) RNG producers are eligible to claim a “K-1” RINs on their volumes of RNG produced, and (2) dispensers are eligible to claim “K-2” RINs on natural gas volumes dispensed as truck fuel, provided they also have a corresponding K-1 RIN to demonstrate the renewable sourcing of gas. The creation of distinct “K-1” and “K-2” RINs creates flexibility for RNG producers to generate and sell K-1 RINs to dispensers independent of the K-2 registration process or dispensing activities. K-1 RINs are only useful for the purpose of registering a K-2 RIN, and K-2 RINs are used to record the environmental offset (similar to a traditional RIN). The introduction of K-1 and K-2 RINs gives rise to a new form of commercial transaction for Opal that is distinct from previous RIN minting arrangements.

On March 26, 2025, the Company entered into a NAESB Base Contract with NextEra (together with certain special conditions, a letter agreement, and an RNG addendum, the "NAESB Contract"). In accordance with the NAESB Contract, the Company could enter into transaction confirmations on a periodic basis for the sale of RNG generated by the RNG Fuels business and NextEra could elect to utilize the Company to market such RNG to generate RINs for NextEra. In March and June 2025, the Company and NextEra entered into such transaction confirmations.

The Company concluded that production and dispensing services represent separate performance obligations. Control over K-1 RINs transfers at the time of gas generation or upon delivery of the RINs. Revenue is recognized at the time control is transferred. The consideration associated with dispensing services is recognized into revenue by the Company when it satisfies its performance obligation by pairing the paperwork associated with the dispensing.

For the three and six months ended June 30, 2025, the Company recognized revenues of $ 5,586 and $ 10,603 , respectively, under the NAESB contract, which were recorded as part of Revenues - RNG Fuel.

Service agreements with related parties

On March 17, 2025, Fortistar, through its subsidiary Wasatch RNG LLC (“Wasatch RNG”), acquired all of the limited liability company interests outstanding in Alpro SD, LLC (“Alpro” and such acquired interest, the “Alpro Interest”). Alpro owns a 50 % limited liability company interest in Wasatch Resource Recovery, LLC (the “Project” or “Wasatch” and such ownership interest, the “Wasatch Interest”) and a 50 % tenancy-in-common interest in certain real estate and operating assets used by Wasatch (the “Project Interest”). The Project captures and converts biogas generated from food waste to produce pipeline quality renewable natural gas (RNG). The Project generates revenue from long-term contracted gas sales, tipping fees, and digestate (fertilizer) sales.

In connection with the acquisition, Fortistar Services 2 LLC and OPAL Fuels LLC entered into an amendment to its existing Administrative Services Agreement, pursuant to which OPAL Fuels will provide certain services to Wasatch RNG in exchange for certain agreed upon fees and expense reimbursements. These services include oversight of the plan to improve the operations and productivity of the Project. Either party may, at its sole election and on ninety ( 90 ) days advance written notice, terminate Company's provision of services to Wasatch Resource Recovery LLC ("Wasatch"), at which time the Management Fee and the Wasatch Remediation Fee shall also terminate.

Additionally, Wasatch RNG and OPAL Fuels entered into an Option Agreement, pursuant to which Wasatch RNG granted an option to OPAL Fuels to purchase the Alpro Interest. The exercise period of the option commenced upon closing of the acquisition and will terminate on the third anniversary of the closing of the acquisition, or ninety days following a change of control of OPAL Fuels. The exercise price of the option would be determined such that Wasatch RNG would earn an internal rate of return on its invested capital of 10 % percent per year if the option is exercised in the first year, 15 % per year if exercised in the second year, and 20 % per year if exercised in the third year.

Wasatch RNG is determined to be a VIE due to their having insufficient equity investment at risk to finance their activities without additional subordinated financial support, and due to the fact that the holder of equity at risk in Wasatch RNG lacks the right to fully receive the expected residual returns. However, we are not the primary beneficiary of this VIE because we do not have the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance. Accordingly, we do not consolidate the results of operations, financial condition and cash flows of Wasatch RNG in our condensed consolidated financial statements.

During the first quarter of 2025, Scott Contino served as Interim CFO of the Company. Pursuant to the Interim Services Agreement, the Company paid Fortistar an agreed hourly rate, such that the monthly fee did not exceed $ 50 , on a cumulative basis.

The following table summarizes revenues recorded from related parties:


	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


	Three Months Ended June 30, 2024						Six Months Ended June 30, 2024
	RNG fuel		Fuel Station Services		Renewable Power		RNG fuel		Fuel Station Services		Renewable Power
Environmental Attributes (1)	$	15,881	$	9,528	$	—	$	31,376	$	17,269	$	—
Commodity swaps (2)	—		—		1,804		—		—		3,330
Environmental processing (3)	—		2,100		—		—		4,439		—
Total	$	15,881	$	11,628	$	1,804	$	31,376	$	21,708	$	3,330

(1) Represents RIN and LCFS sales to NextEra.

(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.

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

The following table summarizes the various fees recorded under the service agreements with related parties which are included in "Selling, general, and administrative" expenses:


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Staffing and management services	$	478	$	534	$	1,110	$	996
Rent - fixed compensation	118		172		348		343
IT services	1,066		800		2,031		1,504
Total	$	1,662	$	1,506	$	3,489	$	2,843

The following table presents the various balances for related parties included in our condensed consolidated balance sheets as of June 30, 2025 and December 31, 2024:


	Location in Balance Sheet	June 30, 2025		December 31, 2024
Assets:
Trade AR - NextEra	Accounts receivable, related party	$	24,183	$	14,522
Receivables from equity method investment entities	Accounts receivable, related party	1,313		—
Total receivables - related party		25,496		14,522
Liabilities:
Payables to equity method investment entities	Accounts payable, related party	7,533		6,946
NextEra	Accounts payable, related party	500		501
Fortistar and Costar (1)	Accounts payable, related party	255		485
Total liabilities - related party		$	8,288	$	7,932

(1) Includes staffing, management and IT services.

Class D Common Stock Conversion

On April 23, 2025, our ultimate controlling shareholder, Fortistar, through its subsidiary OPAL Holdco LLC, exchanged 50 million shares of Class D common stock of the Company held by it, each of which is entitled to five votes per share on all matters on which stockholders generally are entitled to vote, for an equal number of shares of newly issued Class B common stock of the Company, each of which is entitled to one vote on such matters. This transaction had no effect on the economic interest in the Company held by Fortistar.

7. Reportable Segments and Geographic Information

The Company is organized into three operating segments based on the characteristics of its renewable power generation, dispensing portfolio, production and sale of renewable gas, and nature of other products and services.

Our reportable segments disclosure is aligned with the information and internal reporting provided to our CODM. Our Co-CEOs, Adam Comora and Jonathan Maurer, jointly fulfill the role of the CODM. The CODM evaluates performance based on segment net income (loss). For all of the segments, the CODM uses segment net income (loss) in the annual budgeting and monthly forecasting process. The CODM considers budget-to-current forecast and prior forecast-to-current forecast variances for segment net income (loss) on a monthly basis for evaluating performance of each segment and making decisions about allocating capital and other resources to each segment.

The three operating segments are RNG Fuel, Fuel Station Services and Renewable Power. The Company has determined that each of the three operating segments meets the characteristics of a reportable segment under U.S. GAAP.

The Corporate entity is not determined to be an operating segment but is discretely disclosed for purposes of reconciliation of the Company’s consolidated financial statements, and though not denoted as an operating segment, significant expenses are noted within the segment.

The following table reflects the financial data used to calculate each reportable segment’s net income (loss) and includes reconciliations to Opal’s consolidated revenue and consolidated net income (loss) for the three and six months ended June 30, 2025:


Six months ended June 30, 2025 (in thousands)	RNG Fuel		Fuel Station Services		Renewable Power		Corporate		Total
Revenue from external customers	$	52,729	$	97,704	$	15,430	$	—	$	165,863
Intersegment revenues	276		9,285		—		—		9,561

Reconciliation of Revenue
Elimination of intersegment revenues	( 276 )		( 9,285 )		—		—		( 9,561 )
Total consolidated revenues	52,729		97,704		15,430		—		165,863

Less: (1)
Cost of sales and other operating costs	23,380		78,457		13,660		29,607		145,104
Less:
Income from equity method investments	( 1,240 )		—		—		—		( 1,240 )
Interest and financing expense, net	12,404		56		( 28 )		—		12,432
Project development and start up costs	9,558		—		—		—		9,558
Other income	—		—		( 64 )		( 815 )		( 879 )
Depreciation, amortization and accretion	5,954		3,351		1,901		—		11,206
Other segment items (2)	—		( 1,161 )		—		3,723		2,562
Segment Loss	2,673		17,001		( 39 )		( 32,515 )		( 12,880 )

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


Three months ended June 30, 2025 (in thousands)	RNG Fuel		Fuel Station Services		Renewable Power		Corporate	Total
Revenue from external customers	$	25,130	$	47,026	$	8,300	—	$	80,456
Intersegment revenues	138		4,892		—		—	5,030

Reconciliation of Revenue
Elimination of intersegment revenues	( 138 )		( 4,892 )		—		—	( 5,030 )
Total consolidated revenues	25,130		47,026		8,300		—	80,456

Less: (1)
Cost of sales and other operating costs	11,557		38,731		6,898		15,473	72,659
Less:
Income from equity method investments	( 1,962 )		—		—		—	( 1,962 )
Interest and financing expense, net	6,387		( 7 )		( 13 )		—	6,367
Project development and start up costs	3,477		—		—		—	3,477
Other income	—		—		—		( 166 )	( 166 )
Depreciation, amortization and accretion	2,995		1,317		952		—	5,264
Other segment items (2)	—		( 901 )		—		1,845	944
Segment Loss	2,676		7,886		463		( 17,152 )	( 6,127 )

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

(1) The significant expense categories and amounts align with the segment-level information that is regularly provided to the chief operating decision maker. Intersegment expenses are included within the amounts shown.

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

• Fuel Station Services - gain on RNG dispensing, and gain on asset disposal

• Corporate - information technology expense, legal and professional advisor fees, and other overhead expenses

Geographic Information: The Company's assets and revenue generating activities are domiciled in the United States.

The following table reflects certain other financial data for the reportable segments as of June 30, 2025:


(in thousands)	RNG Fuel		Fuel Station Services		Renewable Power		Corporate		Total
Other segment disclosures
Investment in other entities	$	224,577	$	—	$	—	$	—	$	224,577
Segment assets	660,464		179,367		30,361		35,345		905,537

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


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


Six months ended June 30, 2024 (in thousands)	RNG Fuel		Fuel Station Services		Renewable Power		Corporate		Total
Revenue from external customers	$	37,172	$	76,399	$	22,331	$	—	$	135,902
Intersegment revenues	259		10,539		—		—		10,798

Reconciliation of Revenue
Elimination of intersegment revenues	( 259 )		( 10,539 )		—		—		( 10,798 )
Total consolidated revenues	37,172		76,399		22,331		—		135,902

Less: (1)
Cost of sales and other operating costs	16,352		61,273		18,157		23,620		119,402

Less: (1)
Income from equity method investments	( 8,006 )		—		—		—		( 8,006 )
Interest and financing expense, net	9,011		24		( 85 )		—		8,950
Project development and start up costs	3,720		—		—		—		3,720
Depreciation, amortization and accretion	3,358		2,609		2,013		—		7,980
Other segment items (2)	93		( 1,178 )		30		2,326		1,271
Segment Income	12,644		13,671		2,216		( 25,946 )		2,585
Reconciliation of profit or loss (segment income / (loss))
Income tax benefit									—
Consolidated net income									$	2,585


Three months ended June 30, 2024 (in thousands)	RNG Fuel		Fuel Station Services		Renewable Power		Corporate		Total
Revenue from external customers	$	19,445	$	39,257	$	12,248	$	—	$	70,950
Intersegment revenues	259		6,030		—		—		6,289

Reconciliation of Revenue
Elimination of intersegment revenues	( 259 )		( 6,030 )		—		—		( 6,289 )
Total consolidated revenues	19,445		39,257		12,248		—		70,950

Less: (1)
Cost of sales and other operating costs	7,792		30,450		8,900		13,117		60,259

Less: (1)
Income from equity method investments	( 3,800 )		—		—		—		( 3,800 )
Interest and financing expense, net	4,968		46		( 25 )		—		4,989
Project development and start up costs	2,935		—		—		—		2,935
Depreciation, amortization and accretion	1,965		1,291		1,013		—		4,269
Other segment items (2)	232		( 644 )		72		730		390
Segment Income	5,353		8,114		2,288		( 13,847 )		1,908
Reconciliation of profit or loss (segment income / (loss))
Income tax benefit									—
Consolidated net income									$	1,908

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

• Fuel Station Services - gain on recognition of RINs

• Corporate - gain on mark-to-market for OPAL and Sponsor Earnout Awards, loss on extinguishment of debt, insurance other overhead expenses

Geographic Information: The Company's assets and revenue generating activities are domiciled in the United States.

The following table reflects certain other financial data for the reportable segments as of December 31, 2024:


(in thousands)	RNG Fuel		Fuel Station Services		Renewable Power		Corporate		Total
Other segment disclosures
Investment in other entities	$	223,594	$	—	$	—	$	—	$	223,594
Segment assets	635,927		179,304		30,517		35,329		881,077

For the six months ended June 30, 2024, the Company made the following cash payments for capital expenditures:


(in thousands)	RNG Fuel		Fuel Station Services		Renewable Power		Corporate		Total
Cash paid for purchases of property, plant and equipment	$	38,238	$	11,504	$	—	$	—	$	49,742

The tables below outline the revenue from our two major customers, along with their respective percentages of revenue by each segment.


	Six Months Ended June 30,
	2025				2024
Customer A	Revenue		Percentage of total revenue		Revenue		Percentage of total revenue
RNG Fuel	37,833		23	%	31,376		23	%
Fuel Station Services	25,455		15	%	17,269		13	%
Renewable Power	2,654		1	%	3,330		2	%
Total	$	65,942	39	%	$	51,975	38	%


	Six Months Ended June 30,
	2025			2024
Customer B	Revenue	Percentage of total revenue		Revenue	Percentage of total revenue
Fuel Station Services	12,120	7	%	20,377	15	%
Total	12,120	7	%	20,377	15	%


	Three Months Ended June 30,
	2025				2024
Customer A	Revenue		Percentage of total revenue		Revenue		Percentage of total revenue
RNG Fuel	17,732		22	%	15,881		22	%
Fuel Station Services	10,476		13	%	9,528		13	%
Renewable Power	1,488		2	%	1,804		3	%
Total	$	29,696	37	%	$	27,213	38	%


	Three Months Ended June 30,
	2025			2024
Customer B	Revenue	Percentage of total revenue		Revenue	Percentage of total revenue
Fuel Station Services	5,546	7	%	10,464	15	%
Total	5,546	7	%	10,464	15	%

8. Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Equity (Deficit)

Common stock

Share conversion

As of June 30, 2025, there are (i) 30,631,960 shares of Class A common stock issued and 28,996,177 outstanding, (ii) 121,500,000 shares of Class B common stock issued and outstanding (shares of Class B common stock do not have any economic value except voting rights as described below), (iii) no shares of Class C common stock issued and outstanding and (iv) 22,899,037 shares of Class D common stock (shares of Class D common stock do not have any economic value except voting rights as described below).

ATM Program

On November 17, 2023, OPAL Fuels Inc. (the “Company”) entered into an At Market Issuance Sales Agreement (the “Sales Agreement”) with B. Riley Securities, Inc., Cantor Fitzgerald & Co. and Stifel, Nicolaus & Company, Incorporated (each, an “Agent,” and collectively, the “Agents”) pursuant to which the Company may issue and sell shares of its Class A common stock having an aggregate offering price of up to $ 75 million from time to time through the Agents.

The Company will pay each Agent, upon the sale by such Agent of Class A common stock pursuant to the Sales Agreement, an amount equal to up to 3.0 % of the gross proceeds of each such sale of Class A common stock. The Company has also provided the Agents with customary indemnification rights.

The Company issued 17,104 shares of Class A common stock under the ATM Program during the six months ended June 30, 2025 at a price of $ 3.52 and received net proceeds of $ 58 .

The Company issued 36,353 shares of Class A common stock under the ATM Program during the six months ended June 30, 2024 at prices ranging between $ 4.34 and $ 5.68 and received net proceeds of $ 170 .

Redeemable preferred non-controlling interests

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 LLC (a consolidated subsidiary of the Company) from December 31, 2024 to June 30, 2025:


	Series A-1 preferred units			Series A preferred units
	Units	Amount		Units	Amount		Total
Balance, December 31, 2024	300,000	$	30,000	1,000,000	$	100,000	$	130,000
Preferred dividends attributable to Redeemable non-controlling interest	—	1,006		—	3,354		4,360
Preferred dividends attributable to Class A common stockholders	—	202		—	672		874
Payment of Preferred dividends	—	( 1,208 )		—	( 4,026 )		( 5,234 )
Balance, June 30, 2025	300,000	$	30,000	1,000,000	$	100,000	$	130,000

Redeemable non-controlling interests

At each balance sheet date, the Redeemable non-controlling interests are adjusted up to their redemption value if necessary, with an offset in stockholders' deficit. As of June 30, 2025, the Company recorded $ 365,548 as the redemption value based on a five-day VWAP of $ 2.53 per share.

9. Net Loss Per Share

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


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Net income (loss) attributable to Class A common stockholders	$	800	$	( 153 )	$	565	$	( 469 )

Weighted average number of shares of Class A common stock - basic	28,265,710		27,674,567		27,995,258		27,523,150
Dilutive effect of stock options and restricted stock units	963,535		—		693,247		—
Weighted average number of shares of Class A common stock - diluted	29,229,245		27,674,567		28,688,505		27,523,150
Net income (loss) per share of Class A common stock
Basic	$	0.03	$	( 0.01 )	$	0.02	$	( 0.02 )
Diluted	$	0.03	$	( 0.01 )	$	0.02	$	( 0.02 )

The basic income (loss) per share for the three and six months ended June 30, 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.

The following table presents the forms of antidilutive potential common shares:


	As of June 30,
	2025	2024
Stock options	483,502	536,188
Unvested PSUs	2,015,403	694,123
Unvested RSUs	1,104,068	1,809,110
OPAL Fuels Class B units	144,399,037	144,399,037

10. Income taxes

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 sale to a third-party purchaser of certain transferable Investment Tax Credits that had been generated by the Company from its investments in the RNG segment. For the three and six months ended June 30, 2024, the Company recorded $ 0 income tax benefit. The effective tax rate for the three and six months ended June 30, 2025 and 2024 was 0 %. The difference between the Company’s effective tax rate and the U.S. statutory tax rate of 21% was primarily due to a full valuation allowance recorded on the Company’s net U.S. deferred tax assets. 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.

On July 4, 2025, the One Big Beautiful Bill Act (“OBBBA”) was signed into law in the U.S. As the legislation was signed into law after the close of the Company's second quarter, its impacts are not reflected in the Company’s results for the six months ended June 30, 2025. The Company is in the process of evaluating the OBBBA and has not estimated its financial impact at this time.

11. Stock-based compensation

Performance Units

Performance units are contingent upon the Company achieving specified Adjusted EBITDA and production targets. The grant date fair value of these awards was estimated based on the volume-weighted average price of the Company’s Class A common stock on the date of grant. Compensation expense related to these awards is recognized over the performance period based on the estimated probability of achieving the performance conditions as of the reporting date. The applicable performance period for the units granted in 2025 is from January 1, 2025 to December 31, 2027, with all

such units scheduled to vest on March 31, 2028, subject to the achievement of certain performance criteria.


	Number of Units	Weighted-Average Grant-Date Fair Value
Unvested as of December 31, 2024	643,591	$	5.66
Granted	1,477,107	2.04
Vested	( 4,398 )	6.12
Forfeited	( 100,897 )	3.46
Unvested as of June 30, 2025	2,015,403	$	3.08

Restricted stock

The Company’s RSU based payment awards provide recipients with the right to receive shares of Class A common stock upon achievement of vesting conditions. At issuance, the value of the RSU is equal to the value of the per share Class A common stock value. These awards typically include time-based vesting conditions and generally vest over the service period of one to three years .

A summary of the unvested shares as of June 30, 2025, and changes during the six months ended June 30, 2025, is presented below:


	Number of Units	Weighted-Average Grant-Date Fair Value
Unvested as of December 31, 2024	1,886,825	$	5.39
Granted	3,593,691	2.05
Vested	( 546,782 )	5.57
Withheld for settlement of taxes	( 196,533 )	5.90
Forfeited	( 243,850 )	2.81
Unvested as of June 30, 2025	4,493,351	$	2.82

Stock Options

Stock options generally vest over three years and expire ten years from the date of grant.

The fair value of the stock options granted in 2025 was estimated at $ 1.44 per option using the Black-Scholes model. The valuation was based on the following assumptions: share price of $ 2.04 , exercise price of $ 1.53 , expiration of 10 years, annual risk free interest rate of 3.9 % and expected volatility of 50 %.

Stock option activity during the six months ended June 30, 2025, consisted of the following (in thousands, except for share and per share data):


	Stock options	Weighted-Average Exercise Price		Weighted-Average Remaining Contractual Term (Years)
Outstanding as of December 31, 2024	498,661	$	5.65	8.92
Granted	1,166,670	1.53
Cancelled/Forfeited/Expired	( 63,771 )	2.43
Outstanding as of June 30, 2025	1,601,560	2.78		9.36
Vested and exercisable as of June 30, 2025	220,087	$	5.97	8.26

Parent Equity Awards

There were no new residual equity interest grants during the six months ended June 30, 2025.

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,
	2025		2024		2025		2024

2022 Plan	$	2,205	$	1,682	$	3,827	$	2,535
Parent equity awards	—		160		129		320
	$	2,205	$	1,842	$	3,956	$	2,855

12. Commitments and Contingencies

Letters of Credit

As of June 30, 2025 and December 31, 2024, the Company was required to maintain standby letters of credit totaling $ 15,485 and $ 15,120 , 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, 2025:


	Site leases		Office leases		Vehicle and Equipment leases		Total

2025	$	522	$	282	$	809	$	1,613
2026	1,051		47		1,529		2,627
2027	1,129		—		1,035		2,164
2028	1,129		—		347		1,476
2029	1,129		—		—		1,129
2030	1,129		—		—		1,129
Thereafter	17,650		—		—		17,650
	23,739		329		3,720		27,788

Guaranty

On September 13, 2024, OPAL Paragon, an equity method investment of the Company, entered into a tax credit purchase agreement with Apollo Management Holdings, L.P., ("Buyer"), pursuant to which OPAL Paragon sold $ 11,096 of investment tax credits to the Buyer for net proceeds of $ 8,906 . If the tax credits are disallowed or recaptured by the government from the Buyer, OPAL Paragon will be required to return the purchase price and pay any taxes, interests or penalties incurred.

In connection with the above transaction, all of the obligations of OPAL Paragon under such tax credit purchase agreement are guaranteed by the Company.

On March 28, 2025, OPAL Paragon entered into a tax credit purchase agreement with the Buyer, pursuant to which OPAL Paragon sold $ 9,801 of investment tax credits to the Buyer for net proceeds of $ 8,037 . If the tax credits are disallowed or recaptured from the Buyer, OPAL Paragon will be required to return the purchase price and pay any taxes, interests or penalties incurred.

In connection with the above transaction, all of the obligations of OPAL Paragon under such tax credit purchase agreement are guaranteed by the Company.

On June 20, 2025, OPAL Fuels LLC entered into tax credit purchase agreements with the Buyer and EagleBank, pursuant to which OPAL Fuels LLC sold $ 16,740 of investment tax credits for net proceeds of $ 13,686 . If the tax credits are disallowed or recaptured from the Buyer, OPAL Fuels LLC will be required to return the purchase price and pay any taxes, interests or penalties incurred.

In connection with the above transaction, all of the obligations of OPAL Fuels LLC under such tax credit purchase agreements are guaranteed by the Company.

Legal Matters

The Company is involved in various claims arising in the normal course of business. Management believes that the outcome of these claims will not have a material adverse effect on the Company's financial position, results of operations or cash flows.

Set forth below is information related to the Company’s material pending legal proceedings as of the date of this report, other than ordinary routine litigation incidental to the business.

Central Valley Project

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") with CEI 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 submitted a series of change order requests seeking to increase the EPC Contract Price by approximately $ 14 million, 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; 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 schedule in May 2026.

The EPC Agreement requires that CEI, continue working during the course of the litigation and related arbitration proceedings; however, CEI effectively stopped working. Between May and August 2024, MD issued a series of Notices of Default and Demands to Cure to CEI. CEI failed to cure, and on July 30, 2024, MD terminated CEI for default. MD notified CEI’s performance bond surety, Atlantic Specialty Insurance Company of the termination and demanded that it perform under the bond. Atlantic has denied the claim.

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 performance 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 $ 4,900 (MD) and $ 2,000 (VS), and filed actions with the Stanislaus and San Joaquin County Superior Courts, respectively, to enforce their liens. MD and VS have since recorded bonds releasing the properties from the liens and it is expected that these claims will be stayed and consolidated with the pending arbitration proceeding.

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, which the Company is obligated to defend and indemnify the dairy owners from and against. Several of liens were untimely and have been released.

The Company believes its claims against CEI (and the surety where bond claims are denied) have substantial merit, and intends to prosecute the claims vigorously. However, due to the incipient stage of the litigation and related arbitration, the recency of the termination, and the ongoing status of the proceedings and discussions with the bond surety, as well as the uncertainties involved in all litigation and arbitration, the Company is unable at this time to assess the likely outcome of the litigation and related arbitration, the timing of its resolution, or its ultimate impact, if any, on the Central Valley projects or the Company's business, financial condition or results of operations.

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 case is not yet at issue, so no answer or cross claims have been filed yet, and no discovery has been conducted.

13. Subsequent Events

There have been no subsequent events, except as already disclosed, that occurred during such period that would require disclosure in this Form 10-Q or would be required to be recognized in the consolidated financial statements as of and for the three and six months ended June 30, 2025.

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, 2025 and for the three and six months ended June 30, 2025 and 2024, 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, 2024, as filed with the SEC on March 17, 2025. 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

The Company is a vertically integrated leader in the capture and conversion of biogas into low carbon intensity Renewable Power and RNG. OPAL Fuels is 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 is 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) landfill gas, 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.

As of June 30, 2025, we owned and operated 26 projects, 11 of which are RNG projects and 15 of which are Renewable Power Projects. As of that date, our RNG projects in operation had a design capacity of 8.8 million MMBtus per year and our Renewable Power Projects in operation had a nameplate capacity of 105.8 MW per hour. In addition to these projects in operation, we are actively pursuing expansion of our RNG-generating capacity and, accordingly, have a portfolio of RNG projects in construction or in development, with six of our current Renewable Power Projects being considered candidates for conversion to RNG projects in the foreseeable future.

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. We have described below what we believe are our most critical accounting policies, because they generally involve a comparatively higher degree of judgment in their application. 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, 2024. 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, 2024.

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 " elsewhere in this report.

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 June 2023, the EPA set RVOs for 2023 through 2025 via a new Set rule. This 3 year RVO is expected to reduce volatility in RIN pricing for the associated period. 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, respectively, 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 the risk factors in our Annual Report on Form 10-K for the year ended December 31, 2024, including the 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." 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 condensed 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 our 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 we serve 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. The Renewable Power segment generates renewable power and associated Environmental Attributes such as RECs through combustion of biogas from landfills which is then sold to public utilities throughout the United States.

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 royalty payments; 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 start up 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, the Company also incurs 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, 2025 and December 31, 2024. No other single customer accounted for 10% or greater of our consolidated accounts receivables in these periods:


	June 30, 2025		December 31, 2024
Customer A (1)	44	%	31	%
Customer B	17	%	19	%

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

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,
	2025		2024		2025		2024
Customer A	37	%	38	%	39	%	38	%
Customer B	*		15	%	*		15	%

*Less than 10%

Results of Operations for the Three and Six Months Ended June 30, 2025 and 2024

Operational data

The following table summarizes the operational data achieved for the three and six months ended June 30, 2025 and 2024:

RNG Facility Capacity and Utilization Summary


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
RNG Facility Capacity and Utilization
Design Capacity (Million MMBtus) (1)	2.2		1.5		4.4		2.8
Volume of Inlet Gas (Million MMBtus) (2)	1.6		1.1		3.0		2.1
Inlet Design Capacity Utilization (%) (2)	76	%	74	%	73	%	77	%
RNG Fuel volume produced (Million MMBtus)	1.1		0.9		2.2		1.7
Utilization of Inlet Gas (%) (3)	75	%	82	%	76	%	81	%

(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 OPAL’s 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 landfill gas collection system used to recover the landfill gas. The Design Capacity for

each facility will typically be correlated to the amount of landfill gas expected to be generated by the landfill during the term of the related gas rights agreement. The Company expects 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) 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 landfill gas (i.e., concentrations of methane, oxygen, nitrogen, and other gases). The Company generally expects Utilization of Inlet Gas to be in the range of 80% to 90%. Excludes Sunoma and Biotown.


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Renewable Power
Nameplate Capacity (MW per hour) (1)	105.8		105.8		105.8		105.8
Nameplate Capacity for the period (Millions MWh) (1)	0.23		0.23		0.46		0.50
Renewable Power produced (Millions MWh)	0.08		0.09		0.17		0.17
Design Capacity Utilization (%) (2)	35	%	38	%	37	%	37	%

(1) Design Capacity for Renewable Power facilities is the manufacturer’s expected capacity at ISO 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) Design 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), the Company’s Design Capacity Utilization is expected to remain below 50%.


	Three Months Ended June 30,		Six Months Ended June 30,
	2025	2024	2025	2024

RNG Fuel volume produced (Million MMBtus)	1.2	0.9	2.3	1.7
RNG Fuel volume sold (Million GGEs)	20.6	18.7	40.1	35.1
Total volume delivered (Million GGEs)	40.8	36.6	81.4	71.6

RNG projects

Below is a table setting forth the RNG projects in operation and construction in our portfolio as of June 30, 2025:


	OPAL's Share of Design Capacity (MMBtus per year) (1)	Source of Biogas	Ownership	Expected Commercial Operation Date (4)
RNG Projects in Operation:
Greentree	1,061,712	LFG	100%	N/A
Imperial	1,061,712	LFG	100%	N/A
Emerald (2)	1,327,140	LFG	50%	N/A
Sapphire (2)	796,284	LFG	50%	N/A
New River	663,570	LFG	100%	N/A
Noble Road (2)	464,499	LFG	50%	N/A
Pine Bend (2)	424,685	LFG	50%	N/A
Biotown (2)	43,750	Dairy	10%	N/A
Sunoma (3)	176,297	Dairy	90%	N/A
Prince William	1,725,282	LFG	100%	N/A
Polk County	1,060,000	LFG	100%	N/A
Total	8,804,931

RNG Projects in Construction:
Hilltop (5)	255,500	Dairy	100%	(5)
Vander Schaaf (5)	255,500	Dairy	100%	(5)
Burlington (6)	459,900	LFG	50%	(6)
Atlantic (2)	331,785	LFG	50%	Third quarter 2025
Cottonwood (6)	664,884	LFG	100%	(6)
Kirby Canyon (6)	663,570	LFG	100%	(6)
Total	2,631,139

(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 condensed 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) 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.

(5) Please see Part II, Item 1: Legal Proceedings and Note 12 - Commitments and Contingencies to the financial statements.

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

Renewable Power Projects

Below is a table setting forth the Renewable Power projects in operation in our portfolio:


	Nameplate Capacity (MW per Hour) (1)	Current RNG Conversion Candidate (2)
Renewable Power Projects in Operation:
Sycamore	5.2	Yes
Lopez	3.0	—
Miramar Energy	3.2	Yes
San Marcos	1.8	—
Santa Cruz	1.6	—
San Diego - Miramar	6.5	Yes
West Covina	6.5	—
Port Charlotte	2.9	—
Taunton	3.6	—
Arbor Hills (3)	28.9	N/A
C&C	6.3	Yes
Albany	5.9	—
Concord and CMS	14.4	Yes
Pioneer	8.0	—
Richmond (previously "Old Dominion")	8.0	Yes
Total	105.8
Renewable Power projects in construction:
Fall River (4)	2.4	—

(1) Nameplate capacity is the manufacturer’s expected capacity at ISO 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 and (iii) actual productivity of the facility.

(2) We have determined that some of our Renewable Power projects are currently RNG conversion candidates. The Company identifies suitable RNG conversion candidates based on highest return of capital which is driven by certain factors including, but not limited to (i) the quantity and quality of LFG, (ii) the proximity to pipeline interconnect and (iii) the ability to enter into contracts, including site leases and gas rights agreements, with host sites. The Company may change its decision to convert a Renewable Power Project into an RNG project in the future. The Company believes disclosing Renewable Power conversion candidates provides visibility into the effect of those conversions on the existing Renewable Power portfolio.

(3) Although the RNG conversion is completed, it is currently contemplated that the Arbor Hills Renewable Power plant will continue limited operations on a stand-by, emergency basis through March of 2031.

(4) Construction of the Fall River project has been delayed due to permitting issues.

Comparison of the Three and Six Months Ended June 30, 2025 and 2024

The following table presents the period-over-period change for each line item in the Company's statement of operations for the three and six months ended June 30, 2025 and 2024.


	Three Months Ended June 30,				$ Change		% Change		Six Months Ended June 30,				$ Change		% Change
(in thousands)	2025		2024						2025		2024
Revenues:
RNG Fuel	$	25,130	$	19,445	$	5,685	29	%	$	52,729	$	37,172	$	15,557	42	%
Fuel Station Services	47,026		39,257		7,769		20	%	97,704		76,399		21,305		28	%
Renewable Power	8,300		12,248		(3,948)		(32)	%	15,430		22,331		(6,901)		(31)	%
Total revenues	80,456		70,950		9,506		13	%	165,863		135,902		29,961		22	%
Operating expenses:
Cost of sales - RNG Fuel	11,414		8,321		3,093		37	%	23,567		16,659		6,908		41	%
Cost of sales - Fuel Station Services	38,731		30,938		7,793		25	%	78,453		61,273		17,180		28	%
Cost of sales - Renewable Power	6,899		8,899		(2,000)		(22)	%	13,661		18,157		(4,496)		(25)	%
Project development and startup costs	3,477		2,935		542		18	%	9,558		3,720		5,838		157	%
Selling, general, and administrative	17,460		13,699		3,761		27	%	33,427		26,860		6,567		24	%
Depreciation, amortization, and accretion	5,264		4,269		995		23	%	11,206		7,980		3,226		40	%
Income from equity method investments	(1,962)		(3,800)		1,838		48	%	(1,240)		(8,006)		6,766		85	%
Total expenses	81,283		65,261		16,022		25	%	168,632		126,643		41,989		33	%
Operating (loss) income	(827)		5,689		(6,516)		(115)	%	(2,769)		9,259		(12,028)		(130)	%
Other income (expense)
Interest and financing expense, net	(6,367)		(4,989)		(1,378)		(28)	%	(12,432)		(8,950)		(3,482)		(39)	%
Change in fair value of derivative instruments, net	—		776		(776)		(100)	%	281		1,179		(898)		(76)	%
Other income	1,067		432		635		147	%	2,040		1,097		943		86	%
Total other expenses	(5,300)		(3,781)		(1,519)		(40)	%	(10,111)		(6,674)		(3,437)		(51)	%
Net (loss) income before provision for income taxes	(6,127)		1,908		(8,035)		(421)	%	(12,880)		2,585		(15,465)		(598)	%
Income tax benefit	13,686		—		13,686		100	%	21,723		—		21,723		100	%
Net income	7,559		1,908		5,651		296	%	8,843		2,585		6,258		242	%
Net income (loss) attributable to redeemable non-controlling interests	3,982		(753)		4,735		629	%	2,808		(2,380)		5,188		218	%
Net income attributable to non-redeemable non-controlling interests	160		196		(36)		(18)	%	236		198		38		19	%
Dividends on redeemable preferred non-controlling interests	2,617		2,618		(1)		—	%	5,234		5,236		(2)		—	%
Net income (loss) attributable to Class A common stockholders	$	800	$	(153)	$	953	623	%	$	565	$	(469)	$	1,034	220	%

Revenues


(in thousands)	Three Months Ended June 30,						Six Months Ended June 30,
	2025		2024		$ Change		2025		2024		$ Change
RNG Fuel
Brown gas sales	$	4,700	$	909	$	3,791	$	6,157	$	1,908	$	4,249
Environmental Attributes (1)	19,941		18,224		1,717		45,771		34,560		11,211
Other	489		312		177		801		704		97
Total RNG Fuel	25,130		19,445		5,685		52,729		37,172		15,557
Fuel Station Services
OPAL owned stations	8,535		5,795		2,740		15,626		11,170		4,456
RNG marketing (2)	22,773		18,988		3,785		51,299		34,542		16,757
Third party station service and maintenance	8,137		5,962		2,175		15,453		11,192		4,261
Construction	7,581		8,512		(931)		15,326		19,495		(4,169)
Total Fuel Station Services	47,026		39,257		7,769		97,704		76,399		21,305
Renewable Power
Electricity sales	6,328		7,091		(763)		12,637		13,386		(749)
Environmental Attributes (3)	1,972		5,157		(3,185)		2,793		8,945		(6,152)
Total Renewable Power	8,300		12,248		(3,948)		15,430		22,331		(6,901)

Total Revenues	$	80,456	$	70,950	$	9,506	$	165,863	$	135,902	$	29,961

(1) Revenues from Environmental Attributes in the RNG Fuel segment relate to revenues earned from sales of RINs and LCFSs.

(2) Revenues from RNG marketing in the Fuel Station Services segment relate to revenues earned from sales of RINs and LCFSs, as well as revenue from Environmental Attribute generation and monetization services.

(3) Revenues from Environmental Attributes in the Renewable Power segment include revenues earned from sales of ISCC Carbon Credits and RECs.

RNG Fuel

Revenue from RNG Fuel increased by $5.7 million or 29% for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This increase was primarily driven by a $3.8 million increase in brown gas sales due to increase in price and a $1.7 million increase in the sale of environmental attributes. The increase in environmental attributes was related to $5.1 million increase in green gas sales, and $4.5 million increase from the Prince William and Polk facilities, which commenced operations in the second and fourth quarters of 2024, respectively. The increase was partially offset by a $5.3 million decline due to lower RIN prices and $2.5 million decrease in volume.

Revenue from RNG Fuel increased by $15.6 million, or 42%, for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This increase was primarily driven by a $4.2 million increase in brown gas sales due to increase in price and an $11.2 million in the sale of environmental attributes. The increase in environmental attributes was related to $13.7 million increase from the new facilities, $1.9 million increase in RIN volume, and $5.1 million increase in RIN sales on production. The increase was partially offset by a decrease of $9.3 million due to RIN price reduction.

Fuel Station Services

Revenue from Fuel Station Services increased by $7.8 million or 20%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This is primarily due to a $7.0 million increase in RIN volume, a $2.9 million increase in RIN and LCFS minting services (new RNG facilities Prince William, Sapphire, and Polk),

$2.0 million in GGE volume, and $0.7 million in brown gas sales, partially offset by a $5.5 million decrease in third party RIN sales primarily due to lower prices.

Revenue from Fuel Station Services increased by $21.3 million, or 28%, for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This is primarily due to a $13.9 million increase in revenues from RIN and LCFS minting services (new RNG facilities Prince William, Sapphire, and Polk), a $8.9 million increase in RIN volume, and a $3.5 million increase in GGE volume and $0.9 million increase in GGE price, offset by a $5.4 million decrease in third party RIN sales due to lower price, and a $0.6 million decrease in third party sales of LCFSs due to the timing of inventory sales.

Renewable Power

Revenue from Renewable Power decreased by $3.9 million, or 32%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This is primarily due to a $3.2 million loss of revenue resulting from the termination of the ISCC contract in the fourth quarter of 2024, related to the Pioneer, Old Dominion, and West Covina facilities.

Revenue from Renewable Power decreased by $6.9 million, or 31%, for the six months ended June 30, 2025, compared to the six months ended June 30, 2024. This is primarily due to a $6.2 million loss of revenue resulting from the termination of the ISCC contract in the fourth quarter of 2024, related to the Pioneer, Old Dominion, and West Covina facilities.

Cost of sales

RNG Fuel

Cost of sales from RNG Fuel increased by $3.1 million, or 37%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This increase is primarily attributable to $1.4 million increase from Prince William, which commenced operations in the second quarter of 2024, and a $2.2 million increase from Polk, which began operations in the fourth quarter of 2024. The increase was partially offset by a decline in volumes from Sunoma.

Cost of sales from RNG Fuel increased by $6.9 million, or 41%, for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This increase is primarily attributable to a $4.0 million increase from Prince William, which commenced operations in the second quarter of 2024, and a $3.2 million increase from Polk, which began operations in the fourth quarter of 2024.

Fuel Station Services

Cost of sales from Fuel Station Services increased by $7.8 million, or 25%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This is primarily due to an increase of $4.0 million in FPA tolling expense, $1.7 million increase in dispensing fees due to higher credit sales, $1.1 million increase in construction cost and, $0.6 million increase in services and other costs.

Cost of sales from Fuel Station Services increased by $17.2 million, or 28%, for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This is primarily due to a increase of $13.8 million in dispensing fees,$5.5 million increase in FPA tolling expense, offset by decrease in expenditure of $2.1 million in equipment, parts construction and other costs, which are in line with the decrease in construction revenues.

Renewable Power

Cost of sales from Renewable Power decreased by $2.0 million, or 22%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This is primarily due to a $1.3 million decrease in royalties related to the corresponding decrease in ISCC revenues, and a $1.0 million decrease in expenses, which was primarily driven by the timing of major maintenance and other expenses.

Cost of sales from Renewable Power decreased by $4.5 million, or 25% for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This is primarily due to a $2.2 million decrease in royalties related to corresponding decrease in ISCC revenues, and a $2.5 million decrease in expenses, which was primarily driven by the timing of major maintenance and other expenses.

Project development and start up costs

Project development and startup costs increased by $0.5 million, or 18%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This is primarily due to virtual pipeline costs related to Prince William and Polk facilities.

Project development and startup costs increased by $5.8 million, or 157%, for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This is primarily due to virtual pipeline costs related to Prince William and Polk facilities.

Selling, general, and administrative

Selling, general, and administrative expenses increased by a total of $3.8 million, or 27%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This is primarily due to increases in professional fees, compensation costs, stock compensation, and general corporate expenses.

Selling, general, and administrative expenses increased by a total of $6.6 million, or 24%, for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This is primarily due to an increase in professional fees, compensation costs, stock compensation, and general corporate expenses.

Depreciation, amortization, and accretion

Depreciation, amortization, and accretion increased by a total of $1.0 million, or 23%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This is primarily due to depreciation expense on Prince William and Polk, which became operational in the second and fourth quarters of 2024, respectively.

Depreciation, amortization, and accretion increased by a total of $3.2 million, or 40%, for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This is primarily due to depreciation expense on Prince William and Polk, which became operational in the second and fourth quarter of 2024, respectively, as well as additional depreciation expense on fuel station services.

Income from equity method investments

Net income attributable to equity method investments decreased by $1.8 million, or 48%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This is primarily attributable to a decrease in the realized price of RINs sold on operating facilities.

Net income attributable to equity method investments decreased by $6.8 million, or 85% for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This is primarily attributable 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 $1.4 million, or 28%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. This is primarily due to an increase in the drawn balance of the OPAL Term Loan.

Interest and financing expenses, net increased by $3.5 million, or 39%, for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This is primarily due to an increase in the drawn balance of the OPAL Term Loan.

Change in fair value of derivative instruments, net

Change in fair value of derivatives decreased by $0.8 million or 100% for the three months ended June 30, 2025 compared to the three months ended June 30, 2024, due to a lower gain in the current year associated with the mark-to-market adjustments to the earnout liabilities.

Change in fair value of derivatives decreased by $0.9 million or 76% for the six months ended June 30, 2025 compared to the six months ended June 30, 2024 due to a lower gain in the current year associated with the mark-to-market adjustments to the earnout liabilities.

Other income

Other income increased by $0.6 million, or 147% the three months ended June 30, 2025 compared to the three months ended June 30, 2024 mainly due to increase in unrealized gains.

Other income increased by $0.9 million, or 86%, for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. mainly due to increase in unrealized gains.

Income tax benefit

Income tax benefit increased by $13.7 million or 100% for three months ended June 30, 2025 compared to the three months ended June 30, 2024. This is due to receipt of net proceeds from sale of Investment Tax Credits ("ITCs") for Prince William.

Income tax benefit increased by $21.7 million or 100% for the six months ended June 30, 2025 compared to the six months ended June 30, 2024. This is due to receipt of net proceeds from sale of ITCs for Prince William and Sapphire.

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

Net income (loss) attributable to redeemable non-controlling interests increased by $4.7 million, or 629%, for the three months ended June 30, 2025 compared to the three months ended June 30, 2024. The net income for the three months ended June 30, 2025 and 2024 reflects the portion of earnings belonging to OPAL Fuels equity holders. The increase is primarily attributable to higher net income in the current period compared to the same prior-year period.

Net income (loss) attributable to redeemable non-controlling interests for the six months ended June 30, 2025 increased by $5.2 million, or 218%, compared to six months ended June 30, 2024. The increase is primarily attributable to higher net income in the current period compared to the same prior-year period.

Net income attributable to non-redeemable non-controlling interests

Net income attributable to non-redeemable non-controlling interests remained flat for the three months ended June 30, 2025 compared to the three months ended June 30, 2024.

Net income attributable to non-redeemable non-controlling interests remained flat for the six months ended June 30, 2025, compared to six months ended June 30, 2024.

Dividends on redeemable preferred non-controlling interests

Dividends on redeemable preferred non-controlling interests remained flat for the three and six months ended June 30, 2025 compared to the three and six months ended June 30, 2024.

Liquidity and Capital Resources

Liquidity

As of June 30, 2025, our liquidity was $203.2 million, consisting of $138.4 million of unused capacity under our $450 million senior secured credit facility, $35.5 million of unused capacity under the associated revolver, and $29.3 million of cash and cash equivalents.

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 report. Any reduction in demand for our products or our ability to 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.

See Note 3. Borrowings, to our condensed consolidated financial statements.

OPAL Term Loan

In connection with the Credit Agreement Amendment, the Borrower paid the Administrative Agent, for the account of each lender, a one-time nonrefundable fee of $1.25 million.

As of June 30, 2025 and December 31, 2024, the outstanding loan balance (current and non-current) excluding deferred financing costs was $311.6 million and $286.6 million, respectively.

Sunoma Loan

On August 27, 2020, Sunoma, an indirect wholly-owned subsidiary of the Company 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 to $23 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 December 31, 2024, Sunoma is in compliance with the financial covenants under the Sunoma Loan Agreement.

As of June 30, 2025 and December 31, 2024, the outstanding loan balance (current and non-current) excluding deferred financing costs was $20.0 million and $20.8 million, respectively.

The significant assets of Sunoma, as well as those of other consolidated variable VIEs, are parenthesized in the condensed consolidated balance sheets as of June 30, 2025 and December 31, 2024.

Redeemable Series A Preferred Units of OPAL Fuels LLC

In November 2021, NextEra subscribed for an aggregate of $100,000,000 of Series A preferred units issued by OPAL Fuels LLC, a consolidated subsidiary of OPAL Fuels, Inc. The Series A preferred units have limited rights to prevent OPAL Fuels LLC from taking certain actions including (i) major issuances of new debt or equity (ii) executing transactions with affiliates which are not at arm-length basis (iii) major disposition of assets and (iv) major acquisition of assets outside of OPAL Fuels LLC’s primary business. The Series A preferred units are entitled to receive dividends at the rate of 8% per annum. Dividends begin accruing for each unit from the date of issuance and are payable each quarter end regardless of whether they are declared. The dividends are mandatory and cumulative. The Company was allowed to elect to issue additional Series A preferred units ( paid-in-kind) in lieu of cash for the first eight dividend payment dates. As of June 30, 2025 and December 31, 2024, there was no accrued preferred dividend payable.

At any time after issuance, OPAL Fuels LLC may redeem the Series A preferred units for a price equal to original issue price of $100 per unit plus any accrued and unpaid dividends. Upon written notice from NextEra at any time after November 29, 2025, we would be required to redeem the Series A preferred units. In the event the Company does not redeem the Series A preferred units when requested, NextEra will have the following rights and remedies: (1) NextEra’s affiliate may extend the RNG Marketing Agreement by 12 months; or (2) the dividend rate would increase depending on the length of time the Series A preferred units remain unredeemed to up to 20% per annum, and if more than $25,000,000 preferred equity is outstanding for more than six months after November 29, 2025, NextEra may appoint a director to OPAL Fuel Inc.’s Board of Directors; or (3) NextEra may convert the Series A preferred equity into common equity of the OPAL Fuels LLC at a conversion price at a 20% to 30% discount to their value (the discount is 20% during the first 12 months after November 29, 2025, 25% for the next 12 months thereafter and 30% thereafter).

Cash Flows

The following table presents the Company's cash flows for the six months ended June 30, 2025 and 2024:


	Six Months Ended June 30,
(in thousands)	2025		2024
Net cash provided by operating activities	$	21,805	$	14,251
Net cash used in investing activities	(36,026)		(54,080)
Net cash provided by financing activities	18,498		15,036
Net increase (decrease) in cash, restricted cash, and cash equivalents	$	4,277	$	(24,793)

Net Cash Provided by Operating Activities

Net cash provided by operating activities for the six months ended June 30, 2025 was $21.8 million, an increase of $7.6 million compared to $14.3 million for the six months ended June 30, 2024.

The increase was primarily attributable to higher net income driven by increased revenues, lower income from equity method investments, and higher non-cash items. These were partially offset by unfavorable changes in working capital and a decrease in distributions from equity method investments.

Net Cash Used in Investing Activities

Net cash used in investing activities for the six months ended June 30, 2025 was $36.0 million, a decrease of $18.1 million compared to the $54.1 million used in investing activities for the six months ended June 30, 2024.

This was primarily driven by a decrease in payments made for the construction of various RNG generation and dispensing facilities in 2025 compared to 2024, and an increase in distributions received from equity method investments, partially offset by higher contributions made to equity method investments and lower proceeds from the sale of short-term investments.

Net Cash Provided by Financing Activities

Net cash provided by financing activities for the six months ended June 30, 2025 was $18.5 million, an increase of $3.5 million compared to the net cash used in financing activities of $15.0 million for the six months ended June 30, 2024.

This was primarily driven by an increase in proceeds from long-term loans, a decrease in dividend payments on redeemable preferred non-controlling interests, and an increase related to the acquisition of a controlling interest. These were partially offset by long-term loan repayments and higher financing costs paid to third parties.

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, 2025, we anticipate spending of approximately $185.0 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. Borrowings 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

The Company is not required to provide the information required by this Item because it is a “smaller reporting company.”

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, 2025, 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, 2025 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.

Central Valley Project

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") with CEI 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 submitted a series of change order requests seeking to increase the EPC Contract Price by approximately $14 million, 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.

CEI has since recorded mechanic’s liens against each of the projects for $4,900 (MD) and $2,000 (VS), and filed actions with the Stanislaus and San Joaquin County Superior Courts, respectively, to enforce their liens. MD and VS have since recorded bonds releasing the properties from the liens and it is expected that these claims will be stayed and consolidated with the pending arbitration proceeding.

Former Development Partner/Construction Manager

Item 1A. Risk Factors

Except as described below, 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, 2024, filed with the SEC on March 17, 2025, as supplemented by our Quarterly Reports on Form 10-Q. 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.

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.

Our financial performance and growth strategy depend in part on governmental policies that support renewable generation and enhance the economic viability of owning Biogas Conversion Projects or Fueling Stations. These projects currently benefit from various federal, state and local governmental incentives such as investment tax credits, cash grants in lieu of investment tax credits, loan guarantees, Renewable Portfolio Standards (“RPS”) programs, modified accelerated cost-recovery system of depreciation and bonus depreciation. RNG specifically generates meaningful revenue through generation and monetization of Environmental Attributes provided for under several different programs, most commonly, RFS, LCFS and RPS.

Our provision for income taxes is subject to volatility and could be adversely affected by changes in tax laws or regulations, particularly changes in tax incentives in support of energy efficiency. The IRA contains extended and expanded clean energy tax credits such as ITCs, the Production Tax Credit ("PTC"), and created other financial incentives designed to promote the development of certain domestic clean energy projects. In order to receive the full value of such credits and incentives, our projects must satisfy a number of requirements including prevailing wage and apprenticeship requirements. If we fail to comply with these requirements, the value of the credits may be limited, and we may become subject to financial penalties. Uncertainty remains under the IRA on which types of projects are eligible for the tax credits and incentives and how projects can demonstrate compliance with the requirements, we may not receive full value of the tax credits and incentives, which could increase our income tax expense, reduce our net income and adversely impact the profitability of our projects or our ability to finance our projects. The U.S. Congress may look to alter or repeal various energy tax incentives included in the IRA, which could potentially impact projects in development or future project economics. Similarly, recent presidential executive orders directing the review and potential termination of funds appropriated through the IRA are also creating uncertainty of whether these financial incentives could be reduced or repealed in the future. Further, we maybe subject to risks arising from any limitations on the value or availability of tax incentives that benefit clean energy or fuel production, sales, or projects, such as the Section 45Z clean fuel production credit, ITCs, and the PTC, as seen in the accelerated termination of certain clean energy tax credits under the “One Big Beautiful Bill” the U.S. President signed into law on July 4, 2025, which may result in the reduction of such producers’ economic returns.

On November 17, 2023, the Treasury and the IRS proposed regulations regarding ITCs on renewable energy projects where the IRS specified certain types of RNG equipment are ineligible for ITCs which could negatively impact the profitability of our RNG business and our ability to finance our RNG projects. On February 16, 2024, the Treasury and the IRS released a correction to the proposed regulations clarifying that certain of such equipment may be eligible for ITCs. These regulations are merely proposed, and the Treasury and the IRS are collecting and reviewing comments received regarding the proposed regulations. The proposed regulations also contain provisions that we believe create uncertainty relating to the ownership, installation or modification of equipment and property on which ITCs can be claimed. If the final regulations are enacted in a form that limits, in whole or in part, the amount of ITCs for certain of our construction costs, this would reduce the amount of ITCs available and thus could have a material adverse effect on our operations and our business.

There is also uncertainty if IRA incentives may be reduced or repealed in the future, especially in light of the 2024 election results. In addition, the timing of when assets are placed in service has in the past and could in the future impact

our tax rate. If we experience unexpected delays in this timing, we may not be able to take advantage of ITCs as expected. If we are not able to utilize the ITCs as expected this could have an adverse effect of our financial results.

Many states have adopted RPS programs mandating that a specified percentage of electricity sales come from eligible sources of renewable energy. However, the regulations that govern the RPS programs, including pricing incentives for renewable energy and reasonableness guidelines for pricing that increase valuation compared to conventional power (such as a projected value for carbon reduction or consideration of avoided integration costs), may change. If the RPS requirements are reduced or eliminated, it could lead to fewer future power contracts or lead to lower prices for the sale of power in future power contracts, which could have a material adverse effect on our future prospects. Such material adverse effects may result from decreased revenues, reduced economic returns on Biogas Conversion Projects and other potential future investments or joint ventures, increased financing costs, and/or difficulty obtaining financing.

If we are unable to utilize various federal, state and local governmental incentives to acquire additional Biogas Conversion Projects or Fueling Stations in the future, or the terms of such incentives are revised in a manner that is less favorable to us, we may suffer a material adverse effect on our business, financial condition, results of operations and cash flows. In addition, we face similar risks with respect to the RFS program. Any future changes to, federal, state and local regulations and policies, including permitting requirements applicable to us, and enactment of new regulations and policies, may present technical, regulatory and economic barriers to the generation, purchase and use of Renewable Power and RNG, and may adversely affect the market for the associated Environmental Attributes. A failure on our part to comply with any laws, regulations or rules, applicable to us may adversely affect our business, investments and results of operations.

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, 2025, 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.”

New RNG Joint Venture

On May 9, 2025, a wholly-owned indirect subsidiary of the Company, entered into a limited liability company agreement (the “LLC Agreement”) with a leading environmental solutions company (the "Counterparty"), establishing the terms and conditions of governance and operation of a joint venture (the “Joint Venture”). The purpose of the Joint Venture, 70% of which is owned indirectly by the Company and 30% of which is owned by the Counterparty (together, the "Shares"), is to develop, construct, own and operate a facility (the “RNG Facility”) to produce RNG using biogas generated by a certain landfill.

The LLC Agreement governs the terms and conditions of capital contributions to be made by the Joint Venture members to fund the development, construction and operations of the RNG Facility. The LLC Agreement requires members of the Joint Venture to contribute their respective Shares of such capital requirements. The LLC Agreement contemplates that the RNG Facility will be located on a landfill owned by an affiliate of the Counterparty, with a nameplate capacity designed for approximately 5,500 scfm of landfill gas. The representations, warranties and covenants contained in the LLC Agreement were made solely for the benefit of the parties to the LLC Agreement and may be subject to limitations agreed upon by the contracting parties.

The LLC Agreement also provides for the Joint Venture to enter into an agreement with an affiliate of the Counterparty for the contractual rights to purchase landfill gas for the purpose of producing RNG at the RNG Facility (the “RNG Gas Rights Agreement”), as well as the site lease for the RNG Facility (the “RNG Site Lease”). The RNG Gas Rights Agreement and RNG Site Lease expire twenty (20) years from the date of commencement of operations of the RNG Facility. The existing gas rights agreement between an indirect subsidiary of the Company and an affiliate of the Counterparty (which relate to renewable electricity facilities) will terminate in accordance with the provisions of the RNG Gas Rights Agreement.

Further, the LLC Agreement contemplates that the Joint Venture will enter into a management services agreement (the “MSA”), an operations and maintenance agreement (the “O&M Agreement”), and an RNG marketing agreement (the "RNG Marketing Agreement") with certain wholly-owned, indirect subsidiaries of the Company. The MSA will establish terms and conditions for the day-to-day administration of the projects, including responsibility for managing the development and overseeing the construction of the RNG Facility. The O&M Agreement will establish the terms and conditions for operating and maintaining the RNG Facility once construction is completed. The RNG Marketing Agreement will provide for the acquisition, marketing and sale of the environmental attributes associated with RNG produced by the RNG Facility. The definitive terms and conditions of these agreements are not yet established and, accordingly, there is no guarantee that the Joint Venture will enter into each of these agreements.

This summary of the terms of the LLC Agreement does not purport to be complete and is qualified in its entirety by reference to the text of the LLC Agreement, a copy of which is filed as Exhibit 10.1 hereto.

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) .
10.1+#						Limited Liability Company Agreement, dated May 9, 202 5 (incorporated by reference to Exhibit 10.6 to the Quarterly Report on Form 10-Q filed by the Company on May 13, 2025).
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 Securities Exchange Act of 1934, as amended (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.
+						Certain of the schedules and exhibits to this exhibit have been omitted pursuant to Regulation S-K Item 601(a)(5). The Company agrees to furnish supplementally a copy of any omitted schedule or exhibit to the SEC upon its request.
#						Certain confidential information contained in this document has been redacted in accordance with Item 601(b)(10)(iv) of Regulation S-K.

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 7, 2025


OPAL Fuels Inc.

By:			/s/ Jonathan Maurer
Name:			Jonathan Maurer
Title:			Co-Chief Executive Officer


OPAL Fuels Inc.

By:			/s/ Adam Comora
Name:			Adam Comora
Title:			Co-Chief Executive Officer


OPAL Fuels Inc.

By:			/s/ Kazi Hasan
Name:			Kazi Hasan
Title:			Chief Financial Officer

TABLE OF CONTENTS

Part I - Financial Information Item 1. Financial Statements Item 2. Management S Discussion and Analysis Of Financial Condition and Results Of Operations Item 3. Quantitative and Qualitative Disclosures About Market Risk Item 4. Controls and Procedures Part II - Other Information Item 1. Legal Proceedings Item 1A. Risk Factors Item 2. Unregistered Sales Of Equity Securities and Use Of Proceeds Item 3. Defaults Upon Senior Securities Item 4. Mine Safety Disclosures Item 5. Other Information Item 6. Exhibits

Exhibits

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). 10.1+# Limited Liability Company Agreement, dated May 9, 2025(incorporated by reference to Exhibit 10.6 to the Quarterly Report on Form 10-Q filed by the Company on May 13, 2025). 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.

OPAL 10-Q Quarter ended June 30, 2025

Exhibits