10-Q

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 September 30, 2023

or

☐ 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 November 11, 2023, a total of 27,975,260 shares of Class A common stock, par value $0.0001 per share, and 144,399,037 shares of Class D common stock, par value $0.0001 per share were issued and 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, that could cause actual results or outcomes to differ materially from those discussed in the forward-looking statements. Important factors, among others, that 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;

•macroeconomic conditions related to the global COVID-19 pandemic;

•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 29, 2023 (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	1
	Unaudited Condensed Consolidated Balance sheets as of September 30, 2023 And December 31, 2022	1
	Unaudited Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2023 and 2022	3
	Unaudited Condensed Consolidated Statements of Comprehensive Income / (loss) for the three and nine months ended September 30, 2023 and 2022	5
	Unaudited Condensed Consolidated Statements of Changes In Redeemable Non-Controlling Interest, Redeemable Preferred Non-Controlling Interest And Stockholders' (Deficit) Equity for the three and nine months ended September 30, 2023 and 2022	6
	Unaudited Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2023 and 2022	10
	Notes To Unaudited Condensed Consolidated Financial Statements	12
ITEM 2.	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	53
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	66
ITEM 4.	CONTROLS AND PROCEDURES	66
PART II. OTHER INFORMATION
ITEM 1.	LEGAL PROCEEDINGS	69
ITEM 1A.	RISK FACTORS	69
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS, AND ISSUER PURCHASES OF EQUITY SECURITIES	69
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	69
ITEM 4.	MINE SAFETY DISCLOSURES	69
ITEM 5.	OTHER INFORMATION	70
ITEM 6.	EXHIBITS	70
SIGNATURES		72

Part I - Financial Information

Item 1. Financial Statements

OPAL FUELS INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

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

(Unaudited)

	September 30, 2023		December 31, 2022
Assets
Current assets:
Cash and cash equivalents (includes $1,302 and $12,506 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	$	15,000	$	40,394
Accounts receivable, net (includes $79 and $966 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	31,000		31,083
Accounts receivable, related party	—		12,421
Restricted cash - current (includes $1,232 and $6,971 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	1,232		32,402
Short term investments	18,028		64,976
Fuel tax credits receivable	4,386		4,144
Contract assets	14,404		9,771
Parts inventory	11,897		7,311
Environmental credits held for sale (includes $29 and $0 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	4,339		1,674
Prepaid expense and other current assets (includes $193 and $415 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	5,013		7,625
Derivative financial assets, current portion	486		182
Total current assets	105,785		211,983
Capital spares	3,079		3,443
Property, plant, and equipment, net (includes $26,684 and $73,140 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	303,690		297,323
Operating right-of-use assets	12,368		11,744
Investment in other entities	199,466		51,765
Note receivable - variable fee component	2,178		1,942
Derivative financial assets, non-current portion	117		954
Deferred financing costs	—		3,013
Other long-term assets	2,108		1,489
Intangible assets, net	1,700		2,167
Restricted cash - non-current (includes $2,843 and $2,923 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	5,356		4,425
Goodwill	54,608		54,608
Total assets	$	690,455	$	644,856
Liabilities and Equity
Current liabilities:
Accounts payable (includes $603 and $4,896 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	11,309		22,679
Accounts payable, related party (includes $1,035 and $433 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	1,365		1,346
Fuel tax credits payable	3,720		3,320
Accrued payroll	8,313		8,979
Accrued capital expenses (includes $0 and $7,821 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	7,355		11,922

1

Accrued expenses and other current liabilities (includes $602 and $646 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	13,779		9,573
Contract liabilities	7,429		8,013
Senior Secured Credit Facility - term loan, current portion, net of debt issuance costs	—		15,250
Senior Secured Credit Facility - working capital facility, current portion	—		7,500
OPAL Term Loan, current portion	—		27,732
Sunoma Loan, current portion (includes $1,739 and $380 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	1,739		380
Convertible Note Payable	—		28,528
Municipality Loan	—		76
Derivative financial liability, current portion	—		4,596
Operating lease liabilities - current portion	625		630
Other current liabilities	—		1,085
Asset retirement obligation, current portion	1,296		1,296
Total current liabilities	56,930		152,905
Asset retirement obligation, non-current portion	5,267		4,960
OPAL Term Loan, net of debt issuance costs	153,626		66,600
Sunoma Loan, net of debt issuance costs (includes $20,402 and $21,712 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	20,402		21,712
Operating lease liabilities - non-current portion	11,899		11,245
Earn out liabilities	4,291		8,790
Other long-term liabilities	1,163		825
Total liabilities	253,578		267,037
Commitments and contingencies
Redeemable preferred non-controlling interests	130,000		138,142
Redeemable non-controlling interests	1,158,937		1,013,833
Stockholders' deficit
Class A common stock, $0.0001 par value, 340,000,000 shares authorized as of September 30, 2023; 29,332,333 and 29,477,766 shares, issued and outstanding at September 30, 2023 and December 31, 2022, respectively	3		3
Class B common stock, $0.0001 par value, 160,000,000 shares authorized as of September 30, 2023; None issued and outstanding as of September 30, 2023 and December 31, 2022	—		—
Class C common stock, $0.0001 par value, 160,000,000 shares authorized as of September 30, 2023; None issued and outstanding as of September 30, 2023 and December 31, 2022	—		—
Class D common stock, $0.0001 par value, 160,000,000 shares authorized as of September 30, 2023; 144,399,037 and 144,399,037 shares issued and outstanding at September 30, 2023 and December 31, 2022	14		14
Additional paid-in capital	—		—
Accumulated deficit	(841,417)		(800,813)
Accumulated other comprehensive income	70		195
Class A common stock in treasury, at cost; 1,635,783 and 0 shares at September 30, 2023 and December 31, 2022, respectively	(11,614)		—
Total Stockholders' deficit attributable to the Company	(852,944)		(800,601)
Non-redeemable non-controlling interests	884		26,445
Total Stockholders' deficit	(852,060)		(774,156)
Total liabilities, Redeemable preferred non-controlling interests, Redeemable non-controlling interests and Stockholders' deficit	$	690,455	$	644,856

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

2

OPAL FUELS INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

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

(Unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Revenues:
RNG fuel (includes revenues from related party of $18,782 and $15,481 for the three months ended September 30, 2023 and 2022, respectively; $32,909 and $36,326 for the nine months ended September 30, 2023 and 2022, respectively)	$	20,088	$	18,293	$	37,468	$	48,815
Fuel station services (includes revenues from related party of $6,942 and $3,855 for the three months ended September 30, 2023 and 2022, respectively; $10,875 and $12,698 for the nine months ended September 30, 2023 and 2022, respectively)	37,305		35,771		88,089		87,376
Renewable Power (includes revenues from related party of $1,732 and $927 for the three months ended September 30, 2023 and 2022, respectively; $5,006 and $3,196, for the nine months ended September 30, 2023 and 2022, respectively)	13,708		12,486		43,543		32,623
Total revenues	71,101		66,550		169,100		168,814
Operating expenses:
Cost of sales - RNG fuel	8,896		10,872		24,303		27,043
Cost of sales - Fuel station services	31,887		30,837		79,655		74,130
Cost of sales - Renewable Power	11,112		7,645		28,251		23,593
Selling, general, and administrative	13,594		15,751		41,729		34,561
Depreciation, amortization, and accretion	3,739		3,380		10,934		10,101
Total expenses	69,228		68,485		184,872		169,428
Operating income (loss)	1,873		(1,935)		(15,772)		(614)
Other (expense) income:
Interest and financing expense, net	(2,885)		(790)		(4,482)		(7,212)
Loss on debt extinguishment	(953)		—		(2,848)		—
Change in fair value of derivative instruments, net	(138)		(1,908)		4,955		(1,580)
Other income	604		6,308		123,645		6,308
Income from equity method investments	1,726		3,694		1,433		3,658
Income before provision for income taxes	227		5,369		106,931		560
Provision for income taxes	—		—		—		—
Net income	227		5,369		106,931		560
Net (loss) income attributable to redeemable non-controlling interests	(2,104)		4,161		83,123		(2,584)
Net loss attributable to non-redeemable non-controlling interests	(51)		(325)		(531)		(824)
Dividends on Redeemable preferred non-controlling interests (1)	2,782		2,658		8,394		5,093
Net (loss) income attributable to Class A common stockholders	$	(400)	$	(1,125)	$	15,945	$	(1,125)
Weighted average shares outstanding of Class A common stock:
Basic	26,978,969		25,671,390		27,110,953		25,671,390
Diluted	26,978,969		25,823,772		27,683,855		25,823,772
Per share amounts:
Basic	$	(0.01)	$	(0.04)	$	0.59	$	(0.04)
Diluted	$	(0.01)	$	(0.06)	$	0.58	$	(0.06)

3

(1) Paid-in-kind preferred dividend is allocated between redeemable non-controlling interests and Class A common stockholders based on their weighted average percentage of ownership. Please see Note.13 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.

4

OPAL FUELS INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In thousands of U.S. dollars)

(Unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Net income	$	227	$	5,369	$	106,931	$	560
Other comprehensive income:
Effective portion of the cash flow hedge attributable to equity method investments	406		—		515		—
Reclassification adjustments included in earnings (1)	—		—		(1,147)		—
Net unrealized gain (loss) on cash flow hedges	—		1,189		(141)		1,189
Total comprehensive income	633		6,558		106,158		1,749
Net income attributable to Redeemable non-controlling interests	230		6,509		90,166		2,199
Other comprehensive income (loss) attributable to Redeemable non-controlling interests	340		1,011		(649)		1,011
Comprehensive loss attributable to non-redeemable non-controlling interests	(51)		(325)		(531)		(824)
Dividends on Redeemable preferred non-controlling interests	448		310		1,351		310
Comprehensive (loss) income attributable to Class A common stockholders	$	(334)	$	(947)	$	15,821	$	(947)

(1) Represents the reclassification of the gain on termination of interest rate swaps on May 30, 2023. See Note 9 Derivative Financial Instruments for additional information. Additionally, there is $334 reclassification into earnings from our equity method investments.

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

5

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 unit data)

(Unaudited)

	Class A common stock			Class D common stock											Class A common stock in treasury						Mezzanine Equity
	Shares	Amount		Shares	Amount		Additional paid-in capital		Accumulated deficit		Other comprehensive income		Non-redeemable non-controlling interests			Shares	Amount		Total Stockholders' Equity		Redeemable Preferred non-controlling interests		Redeemable non-controlling interests
December 31, 2022	29,477,766	$	3	144,399,037	$	14	$	—	$	(800,813)	$	195	$	26,445		—	$	—	$	(774,156)	$	138,142	$	1,013,833
Net loss	—	—		—	—		—		(1,134)		—		(297)			—	—		(1,431)		—		(5,915)
Other comprehensive loss	—	—		—	—		—		—		(58)		—			—	—		(58)		—		(299)
Proceeds from non-redeemable non-controlling interest	—	—		—	—		1,722		—		—		1,821			—	—		3,543		—		—
Issuance of Class A common stock on warrant exchange	49,633	—		—	—		338		—		—		—			—	—		338		—		—
Cancellation of fractional shares on warrant exchange	(26)	—		—	—		—		—		—		—			—	—		—		—		—
Exercise of put option forward purchase contract - Meteora	—	—		—	—		—		—		—		—			(1,635,783)	(11,614)		(11,614)		—		—
Forfeiture of Class A common stock	(197,258)	—		—	—		—		—		—		—			—	—		—		—		—
Stock-based compensation	—	—		—	—		157		—		—		—			—	—		157		—		814
Change in redemption value of Redeemable non-controlling interests	—	—		—	—		(2,217)		(5,503)		—		—			—	—		(7,720)		—		7,720
Paid-in-kind preferred dividend	—	—		—	—		—		(445)		—		—			—	—		(445)		2,763		(2,318)
March 31, 2023	29,330,115	3		144,399,037	14		—		(807,895)		137		27,969			(1,635,783)	(11,614)		(791,386)		140,905		1,013,835
Net income (loss)	—	—		—	—		—		18,382		—		(183)			—	—		18,199		—		95,851
Other comprehensive loss	—	—		—	—		—		—		(133)		—			—	—		(133)		—		(690)
Proceeds from non-redeemable non-controlling interest	—	—		—	—		1,234		—		—		8,001			—	—		9,235		—		—
Deconsolidation of entities (1)	—	—		—	—		(1,383)		—		—		(34,662)			—	—		(36,045)		—		—
Distributions to non-redeemable non-controlling interests	—	—		—	—		—		—		—		(222)			—	—		(222)		—		—
Stock-based compensation	—	—		—	—		301		—		—		—			—	—		301		—		1,576
Change in redemption value of Redeemable non-controlling interests	—	—		—	—		(152)		40,059		—		—			—	—		39,907		—		(39,907)
Paid-in-kind preferred dividend	—	—		—	—		—		(458)		—		—			—	—		(458)		2,849		(2,391)
June 30, 2023	29,330,115	3		144,399,037	14		—		(749,912)		4		903			(1,635,783)	(11,614)		(760,602)		143,754		1,068,274
Net income	—	—		—	—		—		48		—		(51)			—	—		(3)		—		230
Other comprehensive income	—	—		—	—		—		—		66					—	—		66		—		340

6

Distribution of non-redeemable non-controlling interest	—	—		—	—		(57)	—		—		32		—	—		(25)		—		—
Issuance of Class A common shares for vesting of equity awards	2,218	—		—	—		(20)	—		—		—		—	—		(20)		—		—
Contribution to equity method investments	—	—		—	—		(500)	—		—		—		—	—		(500)		—		—
Change in redemption value of Redeemable non-controlling interests	—	—		—	—		271	(91,105)		—		—		—	—		(90,834)		—		90,834
Payment of paid-in-kind preferred dividends	—	—		—	—		—	—		—		—		—	—		—		(16,536)		—
Stock-based compensation	—	—		—	—		306	—		—		—		—	—		306		—		1,593
Dividends on Redeemable preferred non-controlling interests	—	—		—	—		—	(448)		—		—		—	—		(448)		2,782		(2,334)
September 30, 2023	29,332,333	$	3	144,399,037	$	14	—	$	(841,417)	$	70	$	884	(1,635,783)	$	(11,614)	$	(852,060)	$	130,000	$	1,158,937

(1) As of May 30, 2023, two of our RNG facilities, Emerald and Sapphire (defined below) were deconsolidated and accounted for under equity method as per ASC 323. Please see Note 4 Investment in Other entities and Note 12 Variable Interest Entities for additional information.

7

	Class A common stock			Class D common stock													Mezzanine Equity
	Shares	Amount		Shares	Amount		Additional paid-in capital		Retained earnings		Other Comprehensive income		Non-redeemable non-controlling interests		Total Stockholders' Equity		Redeemable preferred non-controlling interests		Redeemable non-controlling interests
December 31, 2021	—	$	—	144,399,037	$	14	$	—	$	—	$	—	$	1,188	$	1,202	$	30,210	$	63,545
Net loss	—	—		—	—				—		—		(242)		(242)		—		(4,225)
Contributions from non-redeemable non-controlling interest		`		—	—		—		—		—		5,738		5,738		—		(95)
Amortization on payment to acquire non-redeemable noncontrolling interest	—	—		—	—		—		—		—		—		—		—		(91)
Contributions from redeemable preferred non-controlling interests	—	—		—	—		—		—		—		—		—		25,000		(267)
Paid-in-kind preferred dividend				—	—				—		—		—		—		717		(717)
Stock-based compensation				—	—				—		—		—		—				160
March 31, 2022	—	—		144,399,037	14		—		—		—		6,684		6,698		55,927		58,310
Net loss	—	—		—	—		—		—		—		(257)		(257)		—		(85)
Contributions from non-redeemable non-controlling interest	—	—		—	—		—		—		—		11,211		11,211		—		47
Amortization on payment to acquire non-redeemable noncontrolling interest	—	—		—	—		—		—		—		—		—		—		(92)
Contributions from redeemable preferred non-controlling interests	—	—		—	—		—		—		—		—		—		75,000		—
Paid-in-kind preferred dividend	—	—		—	—		—		—		—		—		—		1,718		(1,718)
Stock-based compensation	—	—		—	—		—		—		—		—		—		—		160
June 30, 2022	—	—		144,399,037	14		—		—		—		17,638		17,652		132,645		56,622
Net loss	—	—		—	—		—		(815)				(325)		(1,140)		—		6,509
Unrealized gain cash flow hedges	—	—		—	—		—		—		178		—		178		—		1,011
Issuance of common stock from the reverse capitalization and PIPE investments, net of warrant liability, put option and earnout liabilities	22,611,857	2		—	—		68,255		—		—		—		68,257		—		—
Conversion of Convertible Note Payable to shares of Class A common stock	3,059,533	—		—	—		30,595		—		—		—		30,595		—		—
Proceeds from non-redeemable non-controlling interests	—	—		—	—		(3,158)		—		—		9,361		6,203		—		—
Stock-based compensation	—	—		—	—		19		—		—		—		19		—		140

8

Change in redemption value of Redeemable non-controlling interests	—	—		—	—		(95,711)		(1,065,012)		—		—		(1,160,723)		—		1,160,723
Paid-in-kind preferred dividend	—	—		—	—		—		(310)		—		—		(310)		2,658		$	(2,348)
September 30, 2022	25,671,390	$	2	144,399,037	$	14	$	—	$	(1,066,137)	$	178	$	26,674	$	(1,039,269)	$	135,303	$	1,222,657

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

9

OPAL FUELS INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands of U.S. dollars)

(Unaudited)

	Nine Months Ended September 30,
	2023		2022
Cash flows from operating activities:
Net income	$	106,931	$	560
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Income from equity method investments	(1,433)		(3,658)
Provision for bad debts	492		—
Amortization of operating right-of-use assets	460		518
Depreciation and amortization	10,627		9,866
Amortization of deferred financing costs	1,447		1,514
Loss on debt extinguishment	2,848		—
Loss on warrant exchange	338		—
Gain on deconsolidation of VIEs	(122,873)		—
Gain on extinguishment of contingent liability	—		(4,365)
Gain on repayment of Note receivable	—		(1,943)
Accretion expense related to asset retirement obligation	307		235
Stock-based compensation	4,747		479
Paid-in-kind interest income	(236)		(209)
Change in fair value of Convertible Note Payable	1,579		(151)
Unrealized gain on derivative financial instruments	(4,739)		1,677
Changes in operating assets and liabilities, net of effects of businesses acquired:
Accounts receivable	(409)		(11,269)
Accounts receivable, related party	12,421		—
Proceeds received on previously recorded paid-in-kind interest income	—		288
Fuel tax credits receivable	(242)		(1,049)
Capital spares	364		(308)
Parts inventory	(4,586)		(3,520)
Environmental credits held for sale	(2,665)		(838)
Prepaid expense and other current assets	2,229		(996)
Contract assets	(4,633)		(6,189)
Accounts payable	(931)		(6,734)
Accounts payable, related party	599		323
Fuel tax credits payable	400		690
Accrued payroll	(644)		(2,386)
Accrued expenses	4,195		8,561
Operating lease liabilities - current and non-current	(435)		(518)
Other current and non-current liabilities	(747)		453
Contract liabilities	(584)		(3,035)
Net cash provided by (used in) operating activities	4,827		(22,004)
Cash flows from investing activities:
Purchase of property, plant, and equipment	(92,250)		(85,234)
Proceeds (purchase ) of short term investments	46,948		(146,936)
Cash paid for Investment in other entities	(1,000)		—
Proceeds received from repayment Note Receivable	—		10,855
Deconsolidation of VIEs, net of cash	(11,947)		—
Distributions received from equity method investment	13,331		2,100
Net cash used in investing activities	(44,918)		(219,215)
Cash flows from financing activities:
Proceeds from Sunoma loan	—		4,593

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Proceeds from OPAL Term Loan	174,117		27,500
Proceeds received from Business Combination	—		138,850
Cash paid for purchase of shares upon exercise of put option	(16,391)		—
Financing costs paid to other third parties	(11,062)		(8,462)
Repayment of Senior Secured Credit Facility	(22,750)		(3,674)
Repayment of OPAL Term Loan	(106,090)		(11,277)
Repayment of Municipality loan	(76)		(157)
Repayment of Convertible Note Payable	(30,107)		—
Proceeds from sale of non-redeemable non-controlling interest	12,753		23,152
Cash paid for taxes related to net share settlement of equity awards	(20)		—
Reimbursement of financing costs by joint venture partner	842		—
Payment of paid-in-kind preferred dividends	(16,536)		—
Distribution to non-redeemable non-controlling interest	(222)		—
Proceeds from sale of non-controlling interest, related party	—		100,000
Net cash (used in) provided by financing activities	(15,542)		270,525
Net (decrease) increase in cash, restricted cash, and cash equivalents	(55,633)		29,306
Cash, restricted cash, and cash equivalents, beginning of period	77,221		42,054
Cash, restricted cash, and cash equivalents, end of period	$	21,588	$	71,360
Supplemental disclosure of cash flow information
Interest paid, net of $4,627 and $0 capitalized, respectively	$	3,952	$	7,013
Noncash investing and financing activities:
Paid-in-kind dividend on redeemable preferred non-controlling interests	$	—	$	5,093
Accrual for purchase of Property, plant and equipment included in Accounts payable and Accrued capital expenses	$	7,355	$	9,284
Fair value of Class A common stock issued for redemption of Convertible Note Payable	$	—	$	30,595
Fair value of Derivative warrant liabilities assumed related to Business Combination	$	—	$	13,524
Fair value of Earnout liabilities related to Business Combination	$	—	$	45,900
Fair value of put option to a forward purchase contract related to Business Combination	$	—	$	4,600
Right-of-use assets for finance leases as of January 1, 2022 included in Property, plant and equipment, net	$	—	$	801
Lease liabilities for finance leases as of January 1, 2022 included in Accrued expenses and other current liabilities	$	—	$	316
Lease liabilities for finance leases as of January 1, 2022 included in Other long-term liabilities	$	—	$	485
Fair value of contingent consideration to redeem the non-controlling interest included in Other long-term liabilities	$	—	$	183
Accrual for deferred financing costs included in Accrued expenses and other current liabilities	$	—	$	282

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

11

OPAL FUELS INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Organization and Description of Business

OPAL Fuels Inc. (including its subsidiaries, the "Company", “OPAL,” “we,” “us” or “our”) is a renewable energy company specializing in the capture and conversion of biogas for the (i) production of RNG for use as a vehicle fuel for heavy and medium-duty trucking fleets, (ii) generation of Renewable Power for sale to utilities, (iii) generation and sale of Environmental Attributes associated with RNG and Renewable Power, and (iv) sales of RNG as pipeline quality natural gas. OPAL also designs, develops, constructs, operates and services Fueling Stations for trucking fleets across the country that use natural gas to displace diesel as their transportation fuel. The biogas conversion projects ("Biogas Conversion Projects") currently use landfill gas and dairy manure as the source of the biogas. In addition, OPAL has 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.

The Company is organized into four operating segments based on the characteristics and the nature of products and services. The four operating segments are - RNG Fuel, Fuel Station Services, Renewable Power and Corporate. During the first quarter of 2023, the Company changed its internal reporting to its executive leadership team ("Chief Operating Decision Makers") to change the composition of revenues included in our reportable segments. Please see Note 11 Reportable Segments and Geographic Information for additional information.

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

COVID-19 Impact

In March 2020, the World Health Organization categorized the coronavirus disease 2019 ("COVID-19") as a pandemic and the President of the United States declared the COVID-19 outbreak as a national emergency. Management considered the impact of COVID-19 and determined that, because the Company was deemed an essential business by the U.S. government and did not perform layoffs of personnel or experience a decline in its customer base or business operations, there was no material adverse impact on the Company's statement of position and result of operations as of September 30, 2023, and for the three and nine months ended September 30, 2023.

The future impact of the COVID-19 pandemic on the Company's business will depend on a number of factors, including, but not limited to, the duration and severity of the pandemic and its impact on our customers, all of which are uncertain and cannot be predicted.

2. Summary of Significant Accounting Policies

Basis of Presentation and Principles of Consolidation

These unaudited condensed consolidated financial statements are prepared in accordance with generally accepted accounting principles in the United States ("U.S. GAAP") and include the accounts of the Company and all other entities in which the Company has a controlling financial interest: OPAL Renewable Power LLC (formerly Fortistar Methane 3 LLC (“FM3”) and Fortistar Methane 4 LLC), Beacon RNG LLC (“Beacon”) Sunoma Holdings, LLC (“Sunoma”), New River LLC (“New River”), Reynolds RNG LLC (“Reynolds”), Central Valley LLC (“Central Valley”), Prince William RNG LLC (“Prince William”), Cottonwood RNG LLC, Polk County RNG LLC (“Polk County”), OPAL Contracting LLC (formerly Fortistar Contracting LLC), OPAL RNG LLC (formerly Fortistar RNG LLC), and OPAL Fuel station services LLC (“Fuel Station Services”). The Company’s unaudited condensed consolidated financial statements include the assets and liabilities of these subsidiaries. All intercompany transactions and balances have been eliminated in consolidation. The non-controlling interest attributable to the Company's variable interest entities ("VIE") is presented as a separate component from the Stockholders' deficit in the condensed consolidated balance sheets. It is presented 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 the Stockholders' deficit.

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The accompanying unaudited condensed consolidated financial statements reflect the activities of the Company, its subsidiaries, and its equity method investments for the three and nine months ended September 30, 2023 and 2022. Investments in unconsolidated entities in which the Company has influence over the operating or financial decisions are accounted for under the equity method. On May 30, 2023, the Company together with a third-party environmental solutions company formed Paragon LLC ("Paragon"), a new joint venture holding company. The Company owns 50% of the ownership interest in Paragon. Concurrent to the formation of Paragon, the Company contributed its 50% ownership interests in Emerald and Sapphire to Paragon. Upon the execution of the above transaction, the Company reassessed its equity interests in Emerald RNG LLC ("Emerald") and Sapphire RNG LLC ("Sapphire") under ASC 810, Consolidation and determined that the Company did not have a controlling financial interest in Paragon under ASC 810 because the governance of Paragon is driven by a board jointly controlled equally by the joint venture partner and the Company and there are substantive participating rights held by the joint venture partner in the significant activities of Paragon. As a result of the reassessment, the Company deconsolidated these two entities effective May 30, 2023. Prior to May 30, 2023, the Company consolidated these two entities in accordance with the variable interest entity model guidance under ASC 810, Consolidation.

On September 14, 2023, OPAL Land2Gas LLC (“OPAL L2G”), a wholly-owned indirect subsidiary of OPAL Fuels Inc. (the “Company”), entered into a Limited Liability Company Agreement (for purposes of this paragraph, the “Agreement”) with SJI Landfill RNG LLC (“SJI LRNG”), a wholly-owned indirect subsidiary of South Jersey Industries (“SJI”), establishing the terms and conditions of governance and operation of Land2Gas LLC (the “ SJI Joint Venture”). The purpose of the Joint Venture, which is owned 50/50 by OPAL L2G and SJI LRNG, is to develop, construct, own and operate facilities (“Facilities”) to produce RNG using biogas generated by certain landfills. The Agreement governs the terms and conditions of capital contributions to be made by the SJI Joint Venture members to fund the development, construction and operations of the Facilities. The Agreement requires members of the SJI Joint Venture to contribute their respective share (50% each) of such capital requirements. The Agreement initially contemplates two RNG projects (RNG Atlantic and RNG Burlington) in New Jersey with each RNG project represented as a separate series of membership interests, also owned 50-50 by the members. Further, the Agreement provides for the SJI Joint Venture to enter into a Management Services Agreement (“MSA”), Operations and Maintenance Agreement (“O&M Agreement”), and dispensing agreement with certain wholly-owned, indirect subsidiaries of the Company. The MSA establishes the terms and conditions for the day-to-day administration of the projects, including responsibility for managing the development and overseeing the construction of the Facilities. The O&M Agreement establishes the terms and conditions for operating and maintaining the Facilities once construction is completed. The Dispensing Agreement provides for the acquisition, marketing and sale of the Environmental Attributes associated with RNG produced by the Facilities.

Upon the execution of the above transaction, the Company reassessed its equity interests in the SJI Joint Venture under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in SJI Joint Venture under ASC 810 because the governance of the joint venture is driven by a board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of SJI Joint Venture. As of September 30, 2023, there have been no material contributions made by the Company in the SJI Joint Venture.

As of September 30, 2023, the Company accounted for its ownership interests in Pine Bend RNG LLC ("Pine Bend"), Noble Road RNG LLC ("Noble Road"), Emerald, Sapphire, Paragon, SJI Joint Venture (RNG Atlantic and RNG Burlington) and GREP BTB Holdings LLC ("GREP") under the equity method.

As of December 31, 2022, the Company accounted for its ownership interests in Pine Bend, Noble Road and GREP under the equity method. Please see Note 3. Investment in Other Entities, for additional information.

The accompanying unaudited condensed financial statements have been prepared in accordance with the instructions to Form 10-Q and Article 10 of Regulation S-X of the Securities and Exchange Commission ("SEC"). Certain information or footnote disclosures normally included in financial statements prepared in accordance with U.S. GAAP have been condensed or omitted, pursuant to the rules and regulations of the SEC for interim financial reporting. Accordingly, it does not include all the information and footnotes necessary for a complete presentation of financial position, results of operations, or cash flows. The information herein should be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company's Annual Report. In the opinion of management, the accompanying unaudited condensed financial statements include all adjustments, consisting of a normal recurring nature, which are necessary for a fair statement of the financial position, operating results, and cash flows for the periods presented.

13

Use of Estimates

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

The significant estimates and assumptions of the Company include the residual value of the useful lives of our property, plant and equipment, the fair value of stock-based compensation, asset retirement obligations, the estimated losses on our trade receivables, percentage completion for revenue recognition, incremental borrowing rate for calculating the right-of-use assets and lease liabilities, the impairment assessment of goodwill, the fair value of deconsolidated VIEs 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.

Accounting Pronouncements Adopted

In June 2016, the Financial Standards Accounting Board ("FASB") issued ASU 2016-13, Financial Instruments — Credit Losses ("ASC 326"), with the objective of providing information about the credit risk inherent in an entity’s financial statements as well as to explain management’s estimate of expected credit losses and the changes in the allowance for such losses. The accounting standard amends the current financial instrument impairment model by requiring entities to use a forward-looking approach based on expected losses to estimate credit losses on certain types of financial instruments, including trade receivables. Under the new guidance, an entity recognizes as an allowance, its estimate of lifetime expected credit losses, which will result in more timely recognition of such losses. The Company adopted the accounting standard using the prospective transition approach as of January 1, 2023. The cumulative effect upon adoption was not material to our condensed consolidated financial statements.

The adoption of ASC 326 primarily impacted our trade receivables and the Note receivable - variable fee component recorded on our condensed consolidated balance sheet as of September 30, 2023. Upon adoption of ASC 326, the Company assessed collectability by reviewing accounts receivable on a collective basis where similar characteristics exist and on an individual basis when we identify specific customers with known disputes or collectability issues. In determining the amount of the allowance for credit losses, the Company considered historical collectability based on past due status and made judgments about the creditworthiness of customers based on ongoing credit evaluations. The Company also considered customer-specific information, current market conditions and reasonable and supportable forecasts of future economic conditions to inform adjustments to historical loss data. The carrying value of the Note receivable - variable fee component on the condensed consolidated balance sheet as of September 30, 2023 is based on a discounted expected cash flows model which is adjusted on a quarterly basis. Therefore, the Company determined that the credit risk component is included in the carrying value at each reporting period. The adoption of ASC 326 did not have any material impact on our condensed consolidated financial statements.

Accounting Pronouncements Not Yet Adopted

In March 2023, the FASB issued Accounting Standards Update No. 2023-01, Leases (Topic 842) (the "Update"). The Update requires the entities to classify and account for a leasing arrangement between entities under common control on the same basis as an arrangement with an unrelated party. The Update also requires that leasehold improvements associated with common control leases be amortized by the lessee over the useful life of the leasehold improvements to the common control group (regardless of the lease term) as long as the lessee controls the use of the underlying asset and accounts for the underlying asset as a transfer between entities under common control through an adjustment to equity if and when the lessee no longer controls the use of the underlying asset. The amendments in this Update are effective for fiscal years beginning after December 15, 2023 including interim fiscal periods within those fiscal years. The Company is currently evaluating the impact of the adoption of this Update on its condensed consolidated financial statements.

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. The Company is currently evaluating the impact of the adoption of ASU 2023-05 on its condensed consolidated financial statements.

14

Emerging Growth Company Status

The Company is an emerging growth company as defined in the JOBS Act. The JOBS Act provides emerging growth companies with certain exemptions from public company reporting requirements for up to five fiscal years while a company remains an emerging growth company. As part of these exemptions, the Company is only required to provide two fiscal years of audited financial statements instead of three, is subject to reduced disclosure obligations and is not required to comply with auditor attestation requirements from Section 404(b) of the Sarbanes-Oxley Act regarding our internal control over financial reporting. Additionally, the JOBS Act allows the Company to delay adoption of new or revised financial accounting standards until private companies are required to comply with new or revised financial accounting standards.

Cash, Cash Equivalents, and Restricted Cash

Cash, cash equivalents, and restricted cash consisted of the following as of September 30, 2023 and December 31, 2022:

	September 30, 2023		December 31, 2022
Current assets:
Cash and cash equivalents	$	15,000	$	40,394
Restricted cash - current (1)	1,232		32,402
Long-term assets:
Restricted cash held as collateral (2)	5,356		4,425
Total cash, cash equivalents, and restricted cash	$	21,588	$	77,221

(1) Restricted cash - current as of September 30, 2023 primarily relates to interest reserve on the Sunoma Loan. Restricted cash - current as of December 31, 2022 primarily consists of (i) $16,849 held in escrow to secure the Company's purchase obligations under the forward purchase agreement with Meteora Capital Partners ("Meteora"); (ii) $5,845 equity contribution to a joint venture in connection with the closing of OPAL Term Loan II (iii) $1,127 related to interest reserve on the Sunoma Loan and (iv) $8,581 held in a restricted account for funding one of our RNG projects. The decrease in Restricted cash - current relates to the completed performance of the forward purchase agreement with Meteora and funds spent on construction of our RNG facilities.

(2) Restricted cash held as collateral represents the collateral requirements on our debt facilities.

Short term investments

The Company considers highly liquid investments such as time deposits and certificates of deposit with an original maturity greater than three months at the time of purchase to be short term investments. The short term investments of $18,028 and $64,976 as of September 30, 2023 and December 31, 2022, respectively, consist of commercial paper invested in money market accounts with maturities ranging between 1 and 12 months as of the reporting date. The amounts in these accounts are liquid and available for general use.

Our short term investments are generally invested in commercial paper issued by highly credit worthy counter parties and government-backed treasury bills. Investments are generally not FDIC insured and we take counterparty risk on these investments.

Earnout liabilities

In connection with the business combination ("Business Combination") completed in July 2022 and pursuant to a sponsor letter agreement, ArcLight CTC Holdings II, L.P. (the "Sponsor") 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. OPAL Fuels equity holders are eligible to receive an aggregate of 10,000,000 shares of Class B and Class D common stock upon the Company achieving each earn-out event during the earn-out period. The earnout awards (the "Earnout Awards") were recognized at fair value on the closing date and classified as a liability

15

which is remeasured at each balance sheet date and any change in fair value is recognized in the Company's condensed consolidated statement of operations as part of change in fair value of derivative instruments, net. For the three and nine months ended September 30, 2023, the Company recorded a loss of $(138) and a gain of $4,499, respectively, in its condensed consolidated statement of operations. For the three and nine months ended September 30, 2022, the Company recorded a gain of $6,400 in its condensed consolidated statement of operations. As of September 30, 2023 and December 31, 2022, the Company recorded $4,291 and $8,790, respectively, on its condensed consolidated balance sheets.

Put Option On Forward Purchase Agreement

Prior to the closing of the Business Combination, the Company entered into a Forward Purchase Agreement with Meteora pursuant to which Meteora agreed to purchase 2,000,000 shares of Class A common stock from shareholders who had previously tendered such shares for redemption but agreed to reverse their redemption and sell such shares to Meteora at the redemption price. The Company placed $20,040 in escrow at the closing of the Business Combination to secure its purchase obligation to repurchase these 2,000,000 shares at Meteora’s option for a price of $10.02 per share on the date that is six months after closing of the Business Combination. The put option written to Meteora on 2,000,000 shares of Class A common stock is recorded as a liability under Topic 480 Distinguishing Liabilities from Equity with the change in the fair market value recognized in the statement of operations as part of change in fair value of derivative instruments, net.

On January 23, 2023, pursuant to the terms of the Forward Purchase Agreement, Meteora exercised its option to sell back 1,635,783 shares to the Company. $16,391 of the funds held in escrow which were previously recorded as part of Restricted Cash - current on the Company's consolidated balance sheet as of December 31, 2022 were released to Meteora (excluding accrued interest). In connection with the above, the Sponsor forfeited 197,258 shares of Class A common stock on January 26, 2023 pursuant to the terms of that certain Letter Agreement dated July 21, 2022. The Company treated the repurchased shares as treasury shares and recorded $11,614 representing the fair value of those shares at the closing share price of $7.01 as an adjustment to Stockholders' deficit. Additionally, the Company recorded $4,777 as an offset to the Derivative financial liability - current in its condensed consolidated balance sheet as of September 30, 2023.

Redeemable non-controlling interests

Redeemable non-controlling interests represent the portion of OPAL Fuels that the Company controls and consolidates but does not own. The Redeemable non-controlling interest was created as a result of the Business Combination and represents 144,399,037 Class D 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 statement of operations.

At each balance sheet date, the mezzanine equity classified as Redeemable non-controlling interests is adjusted up to its maximum redemption value if necessary, with an offset in Stockholders' equity. As of September 30, 2023, the maximum redemption value is $1,158,937.

Net Income Per Share

The Company's basic earnings per share of Class A common stock is computed based on the average number of outstanding shares of Class A common stock for the period.

The Company's diluted earnings per share includes effects of the Company's outstanding equity awards under the 2022 Plan (as defined elsewhere in these financial statements), Redeemable non-controlling interests (OPAL Fuels Class B units), redeemable preferred non-controlling interests, Sponsor Earnout Awards and OPAL Earnout Awards.

Accounts Receivable, Net

The Company's allowance for doubtful accounts was $0 and $0 at September 30, 2023 and December 31, 2022, respectively.

Asset Retirement Obligation

The Company accounts for asset retirement obligations in accordance with FASB ASC 410, Asset Retirement and Environmental Obligations, which requires entities to record the fair value of a liability for an asset retirement obligation in

16

the period in which it is incurred and when a reasonable estimate of fair value can be made. The fair value of the estimated asset retirement obligations is recorded as a long-term liability, with a corresponding increase in the carrying amount of the related asset. The discounted asset retirement costs capitalized amounts are accreted over the life of the sublease or site lease agreement. Asset retirement obligations are deemed Level 3 fair value measurements as the inputs used to measure the fair value are unobservable. The Company estimates the fair value of asset retirement obligations by calculating the estimated present value of the cost to retire the asset. This estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental, and political environments. In addition, the Company determines the Level 3 fair value measurements based on historical information and current market conditions.

As of September 30, 2023 and December 31, 2022, the Company estimated the value of its total asset retirement obligations to be $6,563 and $6,256, respectively.

The changes in the asset retirement obligations were as follows as of September 30, 2023:

	September 30, 2023
Balance, December 31, 2022 - Current and non-current	$	6,256
Accretion expense	307
Total asset retirement obligation	6,563
Less: current portion	(1,296)
Total asset retirement obligation, net of current portion	$	5,267

Revenue Recognition

The Company’s revenue arrangements generally consist of a single performance obligation to transfer goods or services. Revenue from the sale of RNG, CNG and electricity is recognized by applying the “right to invoice” practical expedient within the accounting guidance for Revenue from Contracts with Customers that allows for the recognition of revenue from performance obligations in the amount of consideration to which there is a right to invoice the customer and when the amount for which there is a right to invoice corresponds directly to the value transferred to the customer. For some public CNG Fueling Stations where there is no contract with the customer, the Company recognizes revenue at the point in time that the customer takes control of the fuel.

The Company also performs maintenance services throughout the country. Maintenance consists of monitoring equipment and replacing parts as necessary to ensure optimum performance. Revenue from service agreements is recognized over time as services are provided. Capacity payments fluctuate based on peak times of the year and revenues from capacity payments are recognized monthly as earned.

The Company has agreements with two natural gas producers ("Producers") to transport Producers' natural gas using the Company's RNG gathering system. The performance obligation is the delivery of Producers' natural gas to an agreed delivery point on an interstate gas pipeline. The quantity of natural gas transported for the Producers is measured at a certain specified meter. The price is fixed at contracted rates and the Producers pay approximately 30 days after month-end. As such, transportation sales are recognized over time, using the output method to measure progress.

The Company provides credit monetization services to customers that own renewable gas generation facilities. The Company recognizes revenue from these services as the credits are minted on behalf of the customer. The Company receives non-cash consideration in the form of Renewable Identification Numbers ("RINs") or LCFSs for providing these services and recognizes the RINs or LCFSs received as a current asset based on their estimated fair value at contract inception. When the Company receives RINs or LCFSs as payment for providing credit monetization services, it records the non-cash consideration in environmental credits held for sale within the unaudited condensed consolidated balance sheet based on the fair value of RINs or LCFSs at contract commencement.

On November 29, 2021, the Company entered into a purchase and sale agreement with NextEra, a related party for the Environmental Attributes generated by the RNG Fuels business. Under this agreement, the Company plans to sell a minimum of 90% of the Environmental Attributes generated and will receive net proceeds based on the agreed upon price

17

less a specified discount. A specified volume of Environmental Attributes sold per quarter will incur a fee per Environmental Attribute in addition to the specified discount. The agreement was effective beginning January 1, 2022. For the three months ended September 30, 2023 and 2022, the Company earned net revenues after discount and fees of $25,724 and $19,336, respectively. These amounts were recorded as part of Revenues - RNG fuel and Fuel Station Services. For the nine months ended September 30, 2023 and 2022, the Company earned net revenues after discount and fees of $43,784 and $49,024, respectively.

During third and fourth quarter of 2022, two of the wholly-owned subsidiaries from our Renewable Power portfolio entered into a purchase and sale agreement with an environmental attribute marketing firm to sell environmental attributes associated with renewable bio methane ("ISCC Carbon Credits") and purchase brown gas back at contracted fixed prices per million British thermal units ("MMbtu"). One of these contracts has a term of 3 years from the date of certification of the facility with an auto-renewal option. The other contract was terminated in August 2023. During the third quarter of 2023, two additional Renewable Power facilities entered into purchase and sale agreements with 3 year terms and similar terms and conditions as the previous contracts. These two facilities are expected to receive certification in the fourth quarter of 2023. These two facilities are expected to receive certification in the fourth quarter of 2023. For the three and nine months ended September 30, 2023, the Company earned net revenues of $3,732 and $13,425, respectively under this contract which were recorded as part of Revenues - Renewable Power in the unaudited condensed consolidated statement of operations. For the three and nine months ended September 30, 2022, the Company earned net revenues of $842 and recorded as part of Revenues - Renewable Power in the condensed consolidated statement of operations.

Sales of Environmental Attributes such as RINs, renewable energy credits ("RECs"), and LCFS are generally recorded as revenue when the certificates related to them are delivered to a buyer. However, the Company may recognize revenue from the sale of such Environmental Attributes at the time of the related renewable power sales when the contract provides that title to the Environmental Attributes transfers at the time of production, the Company's price to the buyer is fixed, and collection of the sales proceeds is certain.

Management operating fees are earned for the operation, maintenance, and repair of the gas collection system of a landfill site. Revenue is calculated on the volume of per MMBtu of LFG collected and the megawatt hours ("MWhs") produced at that site. This revenue is recognized when LFG is collected and renewable power is delivered.

The Company has various fixed price contracts for the construction of Fueling Stations for customers. Revenues from these contracts, including change orders, are recognized over time, with progress measured by the percentage of costs incurred to date compared to estimated total costs for each contract. This method is used as management considers costs incurred to be the best available measure of progress on these contracts. Costs capitalized to fulfill certain contracts were not material in any of the periods presented.

The Company owns Fueling Stations for use by customers under fuel sale agreements. The Company bills these customers at an agreed upon price for each gallon sold and recognizes revenue based on the amounts invoiced in accordance with the "right to invoice" practical expedient. For some public stations where there is no contract with the customer, the Company recognizes revenue at the point-in-time that the customer takes control of the fuel.

The Company from time-to-time enters into fuel purchase agreements with customers whereby 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. In accordance with the standards of ASC 840, Leases, the Company has concluded that these agreements meet the criteria for a lease and are classified as operating leases. Typically, these agreements do not require any minimum consumption amounts and, therefore, no minimum payments. Upon adoption of ASC 842, the Company adopted the practical expedient not to reassess the classification. For additional information on lease revenues earned, please see Note 8. Leases.

Disaggregation of Revenue

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

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	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Electricity sales	$	8,929	$	9,666	$	26,925	$	27,205
Third party construction	15,182		18,661		37,429		41,476
Fuel Station Service	4,824		3,480		13,728		11,910
Brown gas sales	1,917		12,430		17,268		23,398
Environmental attributes	38,480		19,648		68,848		58,444
Parts sales	629		1,355		1,965		2,332
Operating agreements	—		—		—		893
Other	—		70		—		236
Total revenue from contracts with customers	69,961		65,310		166,163		165,894
Lease revenue	1,140		1,240		2,937		2,920
Total revenue	$	71,101	$	66,550	$	169,100	$	168,814

For the three months ended September 30, 2023 and 2022, 21.4% and 28.0%, respectively of revenue was recognized over time, and the remainder was for products and services transferred at a point in time. For the nine months ended September 30, 2023 and 2022, 22.1% and 24.6%, respectively of revenue was recognized over time, and the remainder was for products and services transferred at a point in time.

Other income

The following table shows the items recorded as Other income:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Loss on warrant exchange	$	—	$	—	$	(338)	$	—
Gain on deconsolidation of VIEs (1)	—		—		122,873		—
Gain on extinguishment of contingent liability	—		4,365		—		4,365
Gain on repayment of Note Receivable	—		1,943		—		1,943
Gain on transfer of non-financial asset in exchange for services received (2)	604		—		1,110		—
Other income	$	604	$	6,308	$	123,645	$	6,308

(1) Represents non-cash gain on deconsolidation of Emerald and Sapphire on May 30, 2023.

(2) Represents the fair value of RINs transferred as consideration for services received.

Contract Balances

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

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	September 30, 2023		December 31, 2022
Accounts receivable, net	$	31,000	$	31,083
Contract assets:
Cost and estimated earnings in excess of billings	$	10,975	$	7,027
Accounts receivable retainage, net	3,429		2,744
Contract assets total	$	14,404	$	9,771
Contract liabilities:
Billings in excess of costs and estimated earnings	$	7,429	$	8,013
Contract liabilities total	$	7,429	$	8,013

During the nine months ended September 30, 2023, the Company recognized revenue of $8,013 that was included in "Contract liabilities" at December 31, 2022. During the nine months ended September 30, 2022, the Company recognized revenue of $9,785 that was included in "Contract liabilities" at December 31, 2021.

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 September 30, 2023, the Company had a Backlog of $46,549 which is anticipated to be recognized as revenue in the next 12 months.

Income Taxes

As a result of the Business Combination, the Company is the sole managing member of OPAL Fuels. OPAL Fuels is a limited liability company that is treated as a partnership for U.S. federal income tax purposes and for most applicable state and local income taxes. Any taxable income or loss generated by OPAL Fuels is passed through to and included in the taxable income or loss of its members, including the Company, on a pro-rata basis, subject to applicable tax regulations.

The Company accounts for income taxes in accordance with ASC Topic 740, Accounting for Income Taxes (“ASC Topic 740”), which requires the recognition of tax benefits or expenses on temporary differences between the financial reporting and tax bases of its assets and liabilities by applying the enacted tax rates in effect for the year in which the differences are expected to reverse. Such net tax effects on temporary differences are reflected on the Company’s unaudited condensed consolidated balance sheets as deferred tax assets and liabilities. Deferred tax assets are reduced by a valuation allowance when the Company believes that it is more-likely-than-not that some portion or all of the deferred tax assets will not be realized. The Company calculates the interim tax provision in accordance with the provisions of ASC Subtopic 740-270, Income Taxes; Interim Reporting. For interim periods, the Company estimates the annual effective income tax rate and applies the estimated rate to the year-to-date income or loss before income taxes.

Significant Customers, Vendors and Concentration of Credit Risk

For the three and nine months ended September 30, 2023, two customers accounted for 49% and 41%, respectively of the Company's revenue. For the three and nine months ended September 30, 2022, two customers accounted for 49% and 45%, respectively of the Company's revenue. At September 30, 2023, one customers accounted for 22% of accounts receivable. At December 31, 2022, two customers accounted for 44% of accounts receivable.

Financial instruments that potentially subject the Company to concentrations of credit risk consist principally of cash and cash equivalents, and trade receivables. The Company places its cash in high credit quality financial institutions located in the United States of America. The Company performs ongoing credit evaluations of its customers.

As of September 30, 2023, two vendors accounted for 39% of the accounts payable. As of December 31, 2022, one vendor accounted for 19% of the accounts payable.

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3. Investment in Other Entities

The Company uses the equity method to account for investments in affiliates that it does not control, but in which it has the ability to exercise significant influence over operating and financial policies. The Company's investments in these nonconsolidated affiliates are reflected in the Company's condensed consolidated balance sheets under the equity method, and the Company's proportionate net (loss) income, if any, is included in the Company's unaudited condensed consolidated statements of operations as (loss) income from equity method investments.

Formation Of A New Joint Venture

On September 14, 2023, OPAL L2G, a wholly-owned indirect subsidiary of the Company, entered into the Agreement with SJI LRNG, a wholly-owned indirect subsidiary of SJI, establishing the terms and conditions of governance and operation of the SJI Joint Venture. The purpose of the SJI Joint Venture, which is owned 50/50 by OPAL L2G and SJI LRNG, is to develop, construct, own and operate Facilities to produce RNG using biogas generated by certain landfills. The Agreement governs the terms and conditions of capital contributions to be made by the SJI Joint Venture members to fund the development, construction and operations of the Facilities. The Agreement requires members of the SJI Joint Venture to contribute their respective share (50% each) of such capital requirements. The Agreement initially contemplates two RNG projects (RNG Atlantic and RNG Burlington) in New Jersey with each RNG project represented as a separate series of membership interests, also owned 50-50 by the members. Further, the Agreement provides for the SJI Joint Venture to enter into a MSA, O&M Agreement, and dispensing agreement with certain wholly-owned, indirect subsidiaries of the Company. The MSA establishes the terms and conditions for the day-to-day administration of the projects, including responsibility for managing the development and overseeing the construction of the Facilities. The O&M Agreement establishes the terms and conditions for operating and maintaining the Facilities once construction is completed. The Dispensing Agreement provides for the acquisition, marketing and sale of the Environmental Attributes associated with RNG produced by the Facilities.

Upon the execution of the above transaction, the Company reassessed its equity interests in the SJI Joint Venture under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in SJI Joint Venture under ASC 810 because the governance of the joint venture is driven by a board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of SJI Joint Venture. As of September 30, 2023, there have been no material contribution made by the Company in the SJI Joint Venture.

Deconsolidation of Emerald and Sapphire

On May 30, 2023, the Company together with a third-party environmental solutions company formed Paragon. The Company owns 50% of the ownership interest in Paragon. Concurrent to the formation of Paragon, the Company contributed its 50% ownership interests in Emerald and Sapphire to Paragon.

On May 30, 2023, OPAL Fuels Intermediate Holdco 2 LLC (“OPAL Intermediate Holdco 2”), a wholly-owned indirect subsidiary of the Company, assigned to Paragon its rights and obligations under its existing senior secured credit facility, OPAL Term Loan II.

Upon the execution of the above two transactions, the Company reassessed its equity interests in Emerald and Sapphire under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in Paragon under ASC 810 because the governance of the Paragon is driven by a board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of Paragon.

Based on the above analysis, the Company determined that it should account for its ownership interests in Paragon under the equity method of accounting pursuant to ASC 323, Investments Equity Method and Joint Ventures, prospectively, as the Company has the ability to exercise significant influence, but not control over the joint venture company.

Prior to May 30, 2023, the Company consolidated these two entities in accordance with the variable interest entity model guidance under ASC 810, Consolidation. Additionally, the Company deconsolidated $2,765 capitalized interest on these two projects. Upon deconsolidation, the Company remeasured the fair value of the retained investment and recognized a gain of $122,873 in the condensed consolidated statement of operations for the nine months ended September 30, 2023 and a corresponding increase in its basis in Investment in Other Entities on its condensed consolidated balance sheet as of September 30, 2023. The Company determined that the gain on deconsolidation is attributable to the

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construction in progress and, therefore, will be amortized over the useful life of the asset which begins on the date the asset is placed in service. The fair value of the retained investment was measured based on a discounted cash flows model in which the future net cash flows from the two RNG facilities were discounted to their present value using a discount factor of 14%.

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

	Pine Bend			Paragon			Noble Road			GREP			Total
Percentage of ownership	50		%	50		%	50		%	20		%
Balance at December 31, 2022	$	22,518		$	—		$	25,165		$	4,082		$	51,765
Deconsolidation of Emerald and Sapphire	—			34,662			—			—			34,662
Deconsolidation of deferred financing costs and capitalized interest	—			1,383			—			—			1,383
Net income from equity method investment (1)	1,884			(1,190)			3,190			(810)			3,074
Reclassification of adjustments into earnings	—			—			—			(334)			(334)
Contribution by the Company (2)	—			500			—			—			500
Distributions from return of investment in equity method investment	(3,525)			(3,585)			(5,700)			(521)			(13,331)
Accumulated other comprehensive income	—			515			—			—			515
Gain on deconsolidation of Emerald and Sapphire (3)	—			122,873			—			—			122,873
Amortization of basis difference (1)	(218)			(388)			(1,035)			—			(1,641)
Balance at September 30, 2023	$	20,659		$	154,770		$	21,620		$	2,417		$	199,466

(1) Reflected in Income from equity method investments in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022.

(2) Represents 50% of the $1,000 contributed by the Company in the third quarter of 2023.

(3) Recorded as part of Other income in our condensed consolidated statement of operations for the three and nine months ended September 30, 2023.

Note receivable

In August 2021, the Company acquired 100% ownership interest in Reynolds which held a Note receivable of $10,450 to Biotown. The Note receivable had a maturity date of July 15, 2027 and carried an interest rate of 12.5% of which 8% is payable in cash on a quarterly basis from the inception of the loan and 4.5% payment-in-kind interest adding to the outstanding debt balance until the facility becomes operational.

On July 15, 2022, Biotown repaid the total amount outstanding under the Note receivable including paid-in-kind interest and prepayment penalty.

The Note receivable also entitles Reynolds to receive 4.25% of any revenue-based distributions made up to a maximum of $4,500 over the term of the debt. The Company recorded the fair value of the Note receivable — variable fee component of $1,538 as an allocation of the initial investment balance of $10,450 and recorded payment-in-kind interest income of $81 and $236 as a reduction in the interest and financing expense, net in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023, respectively. The Company recorded $73 and $209 as a reduction to interest and financing expense, net in its condensed consolidated statement of operations for the three and nine months ended September 30, 2022.

The Note receivable - variable fee component of $2,178 and $1,942 is recorded as a long-term asset on its condensed consolidated balance sheets as of September 30, 2023 and December 31, 2022, respectively.

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The following table summarizes the net income from equity method investments:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Revenue (1)	$	9,463	$	42,158	$	23,927	$	47,247
Gross profit	(11,268)		33,053		(1,392)		34,665
Net income	4,533		31,356		1,634		29,615
Net income from equity method investments (2)	$	1,726	$	3,694	$	1,433	$	3,658

(1) Revenues include a realized gain of $32,796 from commodity swap contracts on our equity method investment, GREP for the three and nine months ended September 30, 2022.

(2) Net income from equity method investments represents our portion of the net income from equity method investments including amortization of any basis differences.

4. Property, Plant, and Equipment, Net

Property, plant, and equipment, net, consisted of the following as of September 30, 2023 and December 31, 2022:

	September 30, 2023		December 31, 2022
Plant and equipment	$	203,473	$	201,655
CNG/RNG fueling stations	46,892		34,567
Construction in progress (1)	150,649		152,105
Buildings	2,585		2,585
Land	1,303		1,303
Service equipment	2,207		1,888
Leasehold improvements	815		815
Vehicles	231		313
Office furniture and equipment	307		307
Computer software	277		277
Vehicles - finance leases	1,708		1,236
Other	571		487
	411,018		397,538
Less: accumulated depreciation	(107,328)		(100,215)
Property, plant, and equipment, net	$	303,690	$	297,323

(1) Includes $4,101 and $3,081 of capitalized interest on our OPAL Term Loan facility as of September 30, 2023 and December 31, 2022.

As of September 30, 2023, the construction in progress balance consists of our investment in the construction of RNG generation facilities including, but not limited to Prince William, Central Valley RNG projects and RNG dispensing facilities. The majority of these facilities, for which costs are in construction in progress as of September 30, 2023, are expected to be operational during the fourth quarter of 2023 and early 2024. As of December 31, 2022, the construction in progress balance consists of our investment in the construction of RNG generation facilities such as Emerald, Sapphire, Prince William, Central Valley and other RNG dispensing facilities.

Depreciation expense on property, plant, and equipment for the three months ended September 30, 2023 and 2022 was $3,485 and $2,992, respectively. The depreciation expense for the nine months ended September 30, 2023 and September 30, 2022 was $10,162 and $9,271, respectively.

5. Intangible Assets, Net

Intangible assets, net, consisted of the following at September 30, 2023 and December 31, 2022:

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	September 30, 2023
	Cost		Accumulated Amortization		Intangible Assets, Net		Weighted Average Amortization Period (Years)
Power purchase agreements	$	8,999	$	(7,889)	$	1,110	18.1
Transmission/distribution interconnection	1,600		(1,019)		581		15.1
Intellectual property	43		(34)		9		5.0
Total intangible assets	$	10,642	$	(8,942)	$	1,700

	December 31, 2022
	Cost		Accumulated Amortization		Intangible Assets, Net		Weighted Average Amortization Period (years)
Power purchase agreements	$	8,999	$	(7,488)	$	1,511	18.1
Transmission/distribution interconnection	1,600		(971)		629		15.1
CNG sales contract	807		(799)		8		10.0
Intellectual property	43		(24)		19		5.0
Total intangible assets	$	11,449	$	(9,282)	$	2,167

Amortization expense for the three and nine months ended September 30, 2023 was $154 and $467, respectively. Amortization expense for the three and nine months ended September 30, 2022 was $197 and $595, respectively. At September 30, 2023, estimated future amortization expense for intangible assets is as follows:

For the remainder of the year ending December 31, 2023	$	81
Fiscal year:
2024	267
2025	267
2026	239
2027	238
Thereafter	608
	$	1,700

6. Goodwill

The following table summarizes the changes in goodwill, if any, by reporting segment from the beginning of the period to the end of the period:

	RNG Fuel		Fuel Station Services		Total
Balance at December 31, 2022	$	51,155	$	3,453	$	54,608
Balance at September 30, 2023	$	51,155	$	3,453	$	54,608

7. Borrowings

The following table summarizes the borrowings under the various debt facilities as of September 30, 2023 and December 31, 2022:

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	September 30, 2023		December 31, 2022
Senior Secured Credit Facility, term loan	$	—	$	15,250
Less: unamortized debt issuance costs	—		—
Less: current portion	—		(15,250)
Senior Secured Credit Facility, term loan, net of debt issuance costs	—		—
Senior Secured Credit Facility, working capital facility	—		7,500
Less: current portion	—		(7,500)
Senior Secured Credit Facility, working capital facility	—		—
OPAL Term Loan	164,118		96,090
Less: unamortized debt issuance costs	(10,492)		(1,758)
Less: current portion	—		(27,732)
OPAL Term Loan, net of debt issuance costs	153,626		66,600
Sunoma Loan	23,000		23,000
Less: unamortized debt issuance costs	(859)		(908)
Less: current portion	(1,739)		(380)
Sunoma Loan, net of debt issuance costs	20,402		21,712
Convertible Note Payable	—		28,528
Less: current portion	—		(28,528)
Convertible Note Payable	—		—
Municipality Loan	—		76
Less: current portion	—		(76)
Municipality Loan	—		—
Non-current borrowings total	$	174,028	$	88,312

As of September 30, 2023, principal maturities of debt are expected as follows, excluding any subsequent refinancing transactions and any undrawn debt facilities as of the date of the condensed consolidated balance sheets:

	OPAL Term Loan		Sunoma Loan		Total
For the remainder of the year ending December 31, 2023	$	—	$	533	$	533
Fiscal year:
2024	—		1,620		1,620
2025	14,771		1,756		16,527
2026	19,694		1,898		21,592
2027	129,653		17,193		146,846
	$	164,118	$	23,000	$	187,118

Senior Secured Credit Facility

On March 20, 2023, the Company repaid in full the remaining outstanding loan under this facility.

On September 21, 2015, FM3, an indirect wholly-owned subsidiary of the Company, entered into a senior secured credit facility (the "Senior Secured Credit Facility") as a borrower and a syndicate of lenders, which provided for an aggregate principal amount of $150,000, consisting of (i) a term loan of $125,000, (ii) a working capital letter of credit facility of up to $19,000 and (iii) a debt service reserve and liquidity facility of up to $6,000. The Company paid $14,300 to the lenders in connection with the transaction.

The loans under the Senior Secured Credit Facility had an interest rate of a fixed margin plus the secured overnight financing rate ("SOFR") for the relevant interest period. The fixed margin is 2.75% for the first four years, then 3.0% until October 8, 2021, and 3.25% thereafter.

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On December 19, 2022, FM3 entered into an Omnibus and Consent Agreement (the “FM3 Amendment”). The FM3 Amendment amended the credit agreement, among other things, to (a) extend the maturity date of the obligations thereunder from December 20, 2022 to March 20, 2023, (b) permit OPAL Fuels to purchase the rights and obligations of certain exiting lenders at par, (c) prepay a portion of the outstanding loans made by the remaining lenders and (d) permit the release of certain project company subsidiaries of FM3 from the collateral securing the obligations under the credit agreement. Upon consummation of the FM3 Amendment, the Company repaid $54,929 of the outstanding term loan.

Patronage dividends

The Company is eligible to receive annual patronage dividends from one of its lenders, Cobank ACB under a profit sharing program. For the three and nine months ended September 30, 2023 and 2022, the Company received cash dividends of $126 and $126, respectively, which were recorded as credits to interest expense in the condensed consolidated statements of operations. Additionally, the Company recorded $489 as a long-term asset in the condensed consolidated balance sheets at September 30, 2023 and December 31, 2022, which represents the Company's equity interest in Cobank SCB. These interests will be redeemed for cash beginning in 2024.

OPAL Term Loan

On October 22, 2021, OPAL Fuels Intermediate Holding Company LLC (“OPAL Intermediate Holdco”), an indirect wholly-owned subsidiary of the Company, entered into a $125,000 term loan agreement (the "OPAL Term Loan") with a syndicate of lenders. As of September 1, 2023, the total outstanding balance on the debt facility was $87,602.

On September 1, 2023, OPAL Intermediate Holdco restructured its existing credit agreement and entered into a new senior secured credit facility with OPAL Intermediate HoldCo as the Borrower, direct and indirect subsidiaries of the Borrower as guarantors (the “Guarantors”), the lenders party thereto, as lenders, Apterra Infrastructure Capital LLC, Barclays Bank PLC, BofA Securities, Inc., Celtic Bank Corporation, Citibank, N.A., JP Morgan Chase Bank, N.A. Investec Inc. and ICBC Standard Bank PLC, as joint lead arrangers, and Bank of America, N.A., as administrative agent. Four of the existing lenders participated in the new credit facility.

The Credit Agreement provides for up to $450.0 million of initial and delayed draw term loans (with such delayed draw term loans available for up to 18 months after closing) and $50.0 million of revolving loans. On September 1, 2023, the Company drew down $144,118 and repaid (1) Intermediate HoldCo’s existing secured indebtedness in the amount of approximately $87,602 plus accrued interest, (2) certain accrued but unpaid returns in the amount of $15,669 of the paid-in-kind preferred dividend on our Redeemable preferred non-controlling interests, and (3) approximately $30,107 of indebtedness on Convertible Note Payable. Additionally, the Company utilized $9,000 of availability under the revolver loan to provide for the issuance of letters of credit to support the operations of the Borrower and Guarantors. The proceeds from the facility are expected to be used to fund other general corporate purposes of the Borrower and Guarantors. The Company paid transaction fees and expenses in the amount of approximately $10,790. The Company drew down additional $20,000 during the third quarter to fund capital expenditure on construction of our RNG projects.

The outstanding loans under the Credit Agreement initially bear interest at an annual rate of Term SOFR plus 3.5%, increasing by 0.25% per annum during the term. Accrued interest on amounts outstanding under the delayed draw term loan facility must be paid on the last day of each applicable interest period. Commencing after the 18-month delayed draw term loan availability period expires, the outstanding principal amount of the term loans amortizes at a rate of 1% per quarter and the Borrower is obligated to pay a leverage based cash sweep ranging from 25% to 100% of distributable cash of Borrower and the Guarantors, and subject to certain other mandatory prepayment requirements. The term loans and revolving loans mature on September 1, 2028.

The Borrower’s and the Guarantors’ obligations under the Credit Agreement are secured by substantially all of their personal property assets (other than certain excluded assets identified in the Credit Agreement) and by a non-recourse pledge of the membership interests of the Borrower.

The Credit Agreement requires the Borrower to maintain a consolidated debt service coverage ratio of not less than 1.2:1.0, as tested on a trailing four fiscal basis as of the last day of each fiscal quarter during the term commencing with the quarter ending December 31, 2023, and to maintain a consolidated debt to cash flow ratio of not greater than 4.5 to 1.0 during the delayed draw availability period, and not greater than 4.0 to 1.0 thereafter.

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The Credit Agreement includes certain customary and project-related affirmative and negative covenants, including restrictions on distributions, and events of default, which include payment defaults breaches of covenants; changes of control materially incorrect or misleading representations or warranties bankruptcy or other events of insolvency and certain project-related defaults. As of September 30, 2023, the Company is in compliance with the financial covenants under the OPAL Term Loan. Additionally, the OPAL Term Loan contains restrictions on distributions and additional indebtedness.

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.

The Company accounted for the above debt restructuring as debt modification for the existing lenders by performing an analysis on a lender by lender basis under ASC 470-50 Debt modifications and exchanges. As a result, the Company recorded debt extinguishment of $953 representing the fees allocated to the lenders who were repaid in full as part of Other income in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023. Additionally, the Company expensed $295 related to third party legal costs as part of Selling, general and administrative expenses in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023.

As of September 30, 2023 and December 31, 2022, the outstanding loan balance (current and non-current) excluding deferred financing costs was $164,118 and $96,090, 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 $20,000. Sunoma paid $635 in financing fees. The loan bears interest at the greater of prime rate plus 3.50%, or 7.75%. The amounts outstanding under the Sunoma Loan are secured by Sunoma's assets.

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. On July 19, 2022, Sunoma completed the conversion of the construction loan into a permanent loan and increased the commitment from $20,000 to $23,000.

The loans under the Sunoma Loan Agreement bear interest at a rate of 7.68% and have a maturity date of July 19, 2033. The Company is required to pay a quarterly amortization of principal of $533 beginning in October 2023.

The significant assets of Sunoma are parenthesized in the condensed consolidated balance sheets as September 30, 2023 and December 31, 2022. See Note 12. Variable Interest Entities for additional information.

Convertible Note Payable

On May 1, 2021, the Company acquired the remaining ownership interests in Beacon and signed an unsecured, contingently convertible note (the "Convertible Note Payable") with ARCC Beacon LLC ("Ares") for a total aggregate amount for $50,000 at an interest rate of 8.00% per annum. The Company had the option to pay interest on the Convertible Note in cash on a quarterly basis or payment-in-kind. The Company chose the option of payment-in-kind interest.

Upon the consummation of the Business Combination, Ares was permitted to choose to convert the total amount outstanding under the Convertible Note to shares of Class A common stock based on a pre-determined conversion formula. Upon completion of the Business Combination in July 2022, Ares elected to convert 50% of the outstanding amount under the Convertible Note to shares of Class A common stock. The Company issued 3,059,533 shares of Class A common stock and redeemed outstanding debt of $30,595.

The Company elected to account for the Convertible Note Payable using the fair value option in accordance with ASC 820, Fair Value Measurement. The fair value was subsequently remeasured on each reporting date and the change in fair value recorded as interest expense in the condensed consolidated statement of operations for each reporting period. The Company repaid the outstanding balance in full on September 1, 2023.

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The Company recorded $(436) and $(1,579) as change in fair value of Convertible Note for the three and nine months ended September 30, 2023, respectively. The Company recorded gains of $2,261 and $151 as change in fair value of the Convertible Note Payable for the three and nine months ended September 30, 2022, respectively as interest and financing expense, net.

Municipality Loan

FM3, an indirect wholly-owned subsidiary of the Company, entered into a loan agreement for the construction of an interconnection that was initially funded by the municipality. The Company made payments to a municipality in the amount of $1,600 plus interest at a fixed annual rate of 3.00% through April 1, 2023. The loan was fully repaid in April 2023.

OPAL Term Loan II

On August 4, 2022, OPAL Intermediate Holdco 2 entered into a new Senior Secured Credit Facility (the "OPAL Term Loan II") with a syndicate of lenders. The indebtedness is guaranteed by certain of the direct and indirect subsidiaries of OPAL Intermediate Holdco 2. The OPAL Term Loan II provides for an approximately two-year delayed term loan facility (the "DDTL Facility") of up to a maximum aggregate principal amount of $100,000 and debt service reserve facility (the "DSR Facility") of up to a maximum aggregate principal amount of $5,000. The proceeds of the DDTL Facility are to be used to fund a portion of the construction of the RNG projects owned, either in full or through a joint venture with a third party, by the subsidiary guarantors. The proceeds of the DSR Facility are to be used solely to satisfy the balance to be maintained in the debt service reserve account. In connection with the transaction, the Company paid $2,200 in financing fees to the lenders and incurred $1,376 in third party fees.

On May 30, 2023, OPAL Intermediate Holdco 2 assigned to Paragon its rights and obligations under OPAL Term Loan II. The joint venture partner of Paragon reimbursed the Company $826 as its portion of the transaction costs incurred.

The Company expensed the remaining deferred financing costs of ($1,895) as loss on debt extinguishment in its condensed consolidated statement of operations for the nine months ended September 30, 2023. There were no amounts outstanding under the OPAL Term Loan II as of May 30, 2023.

Interest rates

2023

For the three and nine months ended September 30, 2023, the weighted average effective interest rate including amortization of debt issuance costs on the Senior Secured Credit Facility was 5.6% including a margin plus SOFR. The debt was repaid in full in March 2023.

For the three and nine months ended September 30, 2023, the weighted average effective interest rate including amortization of debt issuance costs on OPAL Term Loan was 9.2% and 8.0%.

For the three and nine months ended September 30, 2023, the interest rate on the Sunoma Loan was 8.00%.

For the three and nine months ended September 30, 2023, the payment-in-kind interest rate on Convertible Note Payable was 8.00%. The loan was fully repaid in September 2023.

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2022

For the three and nine months ended September 30, 2022, the weighted average effective interest rate on the Senior Secured Credit Facility including amortization of debt issuance costs on Senior Secured Credit Facility was 6.80% and 5.40% including a margin plus LIBOR.

For the three and nine months ended September 30, 2022, the weighted average effective interest rate on the OPAL Term Loan including amortization of debt issuance costs was 6.40% and 5.20%.

For three and nine months ended September 30, 2022, the interest rate on the Sunoma loan was 7.81% and 9.0%, respectively.

For the three and nine months ended September 30, 2022, the payment-in-kind interest rate on Convertible Note Payable was 8.0%.

For the three and nine months ended September 30, 2022, the weighted average interest rate on the Municipality Loan was 3.00%.

The following table summarizes the Company's total interest expense for the three and nine months ended September 30, 2023 and 2022:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Senior Secured Credit Facility	$	—	$	(1,101)	$	(282)	$	(2,543)
Convertible Note Payable mark-to-market	(436)		2,261		(1,579)		151
Sunoma Loan	(454)		(424)		(1,348)		(1,335)
OPAL Term Loan (1)	(1,634)		(1,107)		(1,653)		(2,850)
Commitment fees and other finance fees	(248)		(401)		(560)		(605)
Amortization of deferred financing cost	(652)		(616)		(1,447)		(1,514)
Interest expense on finance leases	(24)		(15)		(61)		(28)
Interest income	563		613		2,448		1,512
Total interest expense	$	(2,885)	$	(790)	$	(4,482)	$	(7,212)

(1) Excludes $842 and $4,627 of interest capitalized and recorded as part of Property, Plant and Equipment for the three and nine months ended September 30, 2023, respectively.

8. Leases

The following are the types of contracts that fall under ASC 842:

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. These are considered to be operating leases with variable consideration. As per ASC 842, the revenue is recognized in the period earned.

Power Purchase Agreements

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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. The Company elected not to reassess the lease classification due to change in criteria under ASC 842 for these two PPAs. There were no amendments to these two contracts after the Adoption Date.

Included in Fuel Station Service revenues are $917 and $2,119 related to the lease portion of the FPAs for the three and nine months ended September 30, 2023, respectively. This includes $856 and $1,906 related to the lease portion of the FPAs for the three and nine months ended September 30, 2022, respectively.

Included in Renewable Power revenues are $223 and $818 related to the lease element of the PPAs for the three and nine months ended September 30, 2023, respectively. Included in Renewable Power revenues are $384 and $1,014 related to the lease element of the PPAs for the three and nine ended September 30, 2022, respectively.

Lessee Contracts

Ground/Site Leases

The Company through various indirectly owned subsidiaries holds site leases on landfills and dairy farms to build RNG generation facilities. Typically, the lease payments over the lease term are immaterial except for three of our RNG facilities including Beacon and two sites at our Central Valley project - MS Digester ("MS") and VS Digester ("VS").

– The lease at the Beacon facility is for 20 years at a monthly rent of $11.

– The lease term for MD and VS is for a period of 20 years from their commercial operation date at a quarterly rent of $125.

On July 5, 2023, the Company through one of its indirectly owned subsidiary entered into a site lease on a dairy farm to build a facility to collect, process and deliver feedstock to an RNG facility. The lease term is 20 years from its commercial operations date at a quarterly rent of $21,250 with a 5% escalator on the calendar quarter in which the fifth anniversary occurs and every fifth anniversary thereafter. The Company recorded $798 as right-of-use operating lease and corresponding lease liability on its condensed consolidated balance sheet as of September 30, 2023 using an incremental borrowing rate of 8.44%,

Additionally, the Company revised the commercial operation date for its leases for MD and VS by 10 months which changed the lease term for both the leases. The Company treated this as a lease modification and increased its right-of-use asset and corresponding lease liability by $280 on its condensed consolidated balance sheet as of September 30, 2023, using the incremental borrowing rate of 8.44%.

Office Lease

The Company entered into a lease for office and warehouse space that became effective upon the termination of the original lease term on January 31, 2018. The term of the lease renewal was 36 months and contained an option to renew for an additional 24 months. In September 2020, the Company exercised this option. In March 2022, the Company entered into an amendment to the lease which extended the lease term till January 2026. The rent for the lease is $26 per month with a built in escalation to $27 from February 1, 2022 to February 1, 2023, $43 from February 1, 2023 - February 1, 2024, $45 from February 1 2024 - February 1, 2025 and $46 for the remaining lease term. The Company accounted for the change in the lease term as a lease modification and reassessed the right-of-use assets and corresponding lease liabilities as of March 31, 2022.

The Company currently shares office space with Fortistar and reimburses Fortistar on a monthly basis at a predetermined rate. The Company determined that this is not a lease under ASC 842 as there is no identifiable asset and the Company does not have the right to control the use of the office space.

The Company determined that the three site leases and the one office lease are operating leases.

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Under ASC 842, leases are classified as either finance or operating arrangements, with such classification affecting the pattern and classification of expense recognition in an entity's income statement. For operating leases, ASC 842 requires recognition in an entity’s income statement of a single lease expense, calculated so that the cost of the lease is allocated over the lease term, generally on a straight-line basis. Right-of-use assets represent a right to use the underlying asset for the lease term and the related lease liability represents an obligation to make lease payments pursuant to the contractual terms of the lease agreement.

Based on the above guidance, the lease expense for the site leases is included as part of Cost of sales - RNG Fuel in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022. The lease expense for the office lease is recorded as part of Selling, general and administrative expenses in its condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022.

Vehicle Leases

The Company leases approximately 65 vehicles in our FM3 and OPAL Fuel Station Services subsidiaries. The leases contain repurchase options at the end of the lease term and the sum total of the lease payments represents substantially the fair value of the asset.

Under ASC 842, the Company determined that the vehicle leases are finance leases. For finance leases, ASC 842 requires recognition of amortization of right-of-use asset as part of depreciation and amortization expense and the interest on the finance lease liability as interest expense in the income statement. The Company accordingly recognized its lease expense on the vehicle leases as part of Depreciation, amortization and accretion expense and interest and financing expense, net in the condensed statement of operations for the three and nine months ended September 30, 2023 and 2022.

Lease Disclosures Under ASC 842

The objective of the disclosure requirements under ASC 842 is to enable viewers of an entity’s financial statements to assess the amount, timing and uncertainty of cash flows arising from lease arrangements. In addition to the supplemental qualitative leasing disclosures included above, below are quantitative disclosures that are intended to meet the stated objective of ASC 842.

Right-of-use assets and Lease liabilities as of September 30, 2023 and December 31, 2022 are as follows:

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Description	Location in Balance Sheet	September 30, 2023		December 31, 2022
Assets:
Operating leases (1):
Site leases	Right-of-use assets	$	11,287	$	10,338
Office lease	Right-of-use assets	1,081		1,406
		12,368		11,744
Finance leases (1):
Vehicle leases	Property, plant and equipment, net	1,708		1,236
		14,076		12,980
Liabilities (1):
Sites leases	Lease liabilities - current portion	126		181
Office lease	Lease liabilities - current portion	499		449
Vehicle leases	Accrued expenses and other current liabilities	577		449
		1,202		1,079
Sites leases	Lease liabilities - non-current portion	11,168		10,135
Office lease	Lease liabilities - non-current portion	731		1,110
Vehicle leases	Other long-term liabilities	1,131		825
		$	13,030	$	12,070

(1) The Operating lease right-of-use asset and Operating lease liabilities represent the present value of lease payments for the remaining term of the lease. The discount rate used ranged from 2.30% to 8.44%.

The table below presents components of the Company's lease expense for the three and nine months ended September 30, 2023 and 2022:

Description	Location in Statement of Operations	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Operating lease expense for site leases	Cost of sales - RNG Fuel	$	263	$	261	$	789	$	785
Operating lease expense for office lease	Selling, general, administrative expenses	121		121		363		363
Amortization of right-of-use assets - finance leases	Depreciation, amortization and accretion expense	155		81		436		245
Interest expense on lease liabilities - finance leases	Interest and financing expense, net	24		15		61		28
		$	563	$	478	$	1,649	$	1,421

The Company does not have material short term lease expense for the three and nine months ended September 30, 2023 and 2022.

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Weighted average remaining lease term (years)	September 30, 2023
Operating leases	19.1 years
Financing leases	3.1 years
Weighted average discount rate
Operating leases	7.84	%
Financing leases	6.39	%

The table below provides the total amount of lease payments on an undiscounted basis on our lease contracts as of September 30, 2023:

	Site leases			Office leases			Vehicle leases			Total
Discount rate upon adoption	5.4		%	2.3		%	7.6		%
2023	$	261		$	130		$	147		$	538
2024	1,058			540			667			2,265
2025	1,129			562			561			2,252
2026	1,129			47			406			1,582
2027 and beyond	20,145			—			115			20,260
	23,722			1,279			1,896			26,897
Present value of lease liability	11,294			1,230			1,708			14,232
Lease liabilities - current portion	126			499			577			1,202
Lease liabilities - non-current portion	11,168			731			1,131			13,030
Total lease liabilities	$	11,294		$	1,230		$	1,708		$	14,232
Discount based on incremental borrowing rate	$	12,428		$	49		$	188		$	12,665

9. Derivative Financial Instruments and Fair Value Measurements

Interest Rate Swaps

During August 2022, the Company entered into two interest rate swaps for the notional amount of $61,926 of the OPAL Term Loan II at a fixed interest rate of 2.47% to hedge the SOFR-based floating interest rate. On August 16, 2022, the Company entered into a swaption for a notional amount of $13,074 with fixed rate of 2.32% with a maturity date of May 31, 2023. The Company accounted for the swaption as an economic hedge and included the change in the fair market value in the condensed consolidated statement of operations.

The two interest rate swaps were designated and qualified as cash flow hedges. The Company uses interest rate swaps for the management of interest rate risk exposure, as an interest rate swap effectively converts a portion of the Company’s debt from a floating to a fixed rate. The interest rate swap is an agreement between the Company and counterparties to pay, in the future, a fixed-rate payment in exchange for the counterparties paying the Company a variable payment. The amount of the net payment obligation is based on the notional amount of the interest rate swap and the prevailing market interest rates. The Company may terminate the interest rate swaps prior to their expiration dates, at which point a realized gain or loss may be recognized, or may be amortized over the original life of the interest rate swap if the hedged debt remains outstanding. The value of the Company’s commitment would increase or decrease based primarily on the extent to which interest rates move against the rate fixed for each swap.

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The Company records the fair value of the interest rate swap as an asset or liability on its balance sheet. The effective portion of the swap is recorded in Accumulated other comprehensive income.

On May 30, 2023, OPAL Intermediate Holdco 2, assigned to Paragon its rights and obligations under the OPAL Term Loan II. Concurrently, the Company terminated the two interest rate swaps outstanding under this loan and received $812 as settlement from the swap counterparty. Paragon entered into four interest rate swaps for a notional amount of $56,914 at a fixed interest rate of 3.52%. The Company terminated the swaption on the same date.

After the transaction, the Company recognized a gain of $812 in the condensed consolidated statement of operations for the nine months ended September 30, 2023 as part of Change in fair value of derivative instruments. The Company received $136 as a settlement from the swaption counterparty and recognized $46 as loss on termination of the swaption as part of change in fair value of derivative instruments. Additionally, the Company recognized $515 as its share of the Accumulated other comprehensive income from Paragon and increased its basis in equity method investment on its condensed consolidated balance sheet as of September 30, 2023.

The following table summarizes the interest rate swaps in place as of September 30, 2023 and December 31, 2022:

Interest rate swap detail					Notional Amount
Trade date	Fixed rate		Start date	End date	September 30, 2023		December 31, 2022
August 15, 2022	2.47	%	June 28, 2024	August 4, 2027	$	—	41,284
August 15, 2022	2.47	%	June 28, 2024	August 4, 2027	—		20,642
					$	—	$	61,926

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

	September 30, 2023		December 31, 2022		Location of Fair Value Recognized in Balance Sheet
Derivatives designated as economic hedges:
Current portion of swaption	$	—	$	182	Derivative financial assets, current portion
Derivatives designated as cash flow hedges:
Long term portion of the interest rate swaps	—		954		Derivative financial assets, non-current
	$	—	$	1,136

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

	Three Months Ended September 30,				Nine Months Ended September 30,				Location of (Loss) Gain Recognized in Operations from Derivatives
	2023		2022		2023		2022
Interest rate swaps	$	—	$	1,580	$	—	$	954
Swaption	—		246		(46)		246
Net periodic settlements	—		(1,631)		812		(677)
	$	—	$	195	$	766	$	523	Change in fair value of derivative instruments, net

The following table summarizes the fair value of derivative instruments on the Company's condensed consolidated balance sheets and the effect of netting arrangements and collateral on its financial position:

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	Gross Amounts of Recognized Assets		Gross Amounts Offset in the Balance Sheet		Net Amounts of Assets in the Balance Sheet
Balance, September 30, 2023:
Interest rate swap asset	$	—	$	—	$	—
Swaption asset	—		—		—
	$	—	$	—	$	—
Balance, December 31, 2022:
Interest rate swap asset	$	954	$	—	$	954
Swaption asset	182		—		182
	$	1,136	$	—	$	1,136

Commodity Swap Contracts

The Company utilizes commodity swap contracts to hedge against the unfavorable price fluctuations in market prices of electricity. The Company does not apply hedge accounting to these contracts. As such, unrealized and realized gain (loss) is recognized as a component of Renewable Power revenues in the condensed consolidated statement of operations and Derivative financial asset — current and non-current in the condensed consolidated balance sheets. These are considered to be Level 2 instruments in the fair value hierarchy. By using commodity swaps, the Company exposes itself to credit risk and market risk. Credit risk is the failure of the counterparty to perform under the terms of the swap contract. When the fair value of the swap contract is positive, the counterparty owes the Company creating a credit risk. The Company manages the credit risk by entering into contracts with financially sound counterparties. To mitigate this risk, management monitors counterparty credit exposure on an annual basis, and the necessary credit adjustments have been reflected in the fair value of financial derivative instruments. When the fair value of the swap contract is negative, the Company owes the counterparty creating a market risk that the market price is higher than the contract price resulting in the Company not participating in the opportunity to earn higher revenues.

In December 2018, the Company signed an amendment that converted an existing PPA into a commodity swap contract to allow the Company flexibility to sell the capacity separately and schedule the sale of electricity to independent third parties. Following the amendment, the Company agreed to net settle the contract in cash on a monthly basis based on the difference between the contract price and market price. The contract has a default minimum of 34,554 MWh per year. Additionally, the Company entered into an ISDA agreement with a counterparty in November 2019. Pursuant to the agreement, the Company entered into swaps with contract prices ranging between $35.75 and $51.25 per MWh.

The following table summarizes the commodity swaps in place as of September 30, 2023 and December 31, 2022. There were no new commodity swap contracts entered during the three months ended September 30, 2023.

Trade Date	Period From	Period To	Notional Quantity per Year (“MWh”)	Average Contract Price (per MWh)
October 17, 2022	January 1, 2023	December 31, 2024	70,176	$	68.50
October 17, 2022	January 1, 2023	December 31, 2024	26,280	$	65.50
November 17, 2022	January 1, 2023	December 31, 2024	35,088	$	81.50

The following table summarizes the effect of commodity swaps on the condensed consolidated statements of operations for the three and nine months ended September 30, 2023 and 2022:

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Derivatives not designated as hedging instruments	Location of (loss) gain recognized	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Commodity swaps - realized (loss) gain	Revenues - Renewable power	$	493	$	(744)	$	1,373	$	(931)
Commodity swaps - unrealized gain (loss)	Revenues - Renewable power	(30)		161		733		(775)
Total realized and unrealized gain (loss)	Revenues - Renewable power	$	463	$	(583)	$	2,106	$	(1,706)

The following table summarizes the derivative assets and liabilities related to commodity swaps as of September 30, 2023 and December 31, 2022:

	Fair Value				Location of Fair value recognized in Balance Sheet
	September 30, 2023		December 31, 2022
Derivatives designated as economic hedges
Current portion of unrealized gain on commodity swaps	$	486	$	—	Derivative financial asset, current portion
Non-current portion of unrealized gain on commodity swaps	$	117	$	—	Derivative financial asset, non-current portion
Current portion of unrealized loss on commodity swaps	$	—	$	(130)	Derivative financial liability, current portion

Other Derivative Liabilities

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 September 30, 2023 and 2022:

Derivative liability	Three Months Ended September 30,				Nine Months Ended September 30,				Location of (Loss) Gain Recognized in Operations from Derivatives
	2023		2022		2023		2022
Put option to Meteora	$	—	$	384	$	(311)	$	384
Sponsor Earnout Awards	(338)		1,100		(201)		1,100
OPAL Earnout Awards	200		5,300		4,701		5,300
Public Warrants	—		(3,578)		—		(3,578)
Private Warrants	—		(5,309)		—		(5,309)
	$	(138)	$	(2,103)	$	4,189	$	(2,103)	Change in fair value of derivative instruments, net

Fair Value Measurements

The fair value of financial instruments, including long-term debt and derivative instruments is defined as the amount at which the instruments could be exchanged in a current transaction between willing parties. 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 is considered Level 2 in the fair value hierarchy, of $174,028 and $88,312 as of September 30, 2023 and December 31, 2022, respectively, represents the total amount to be repaid if the debt has to be discharged in full and therefore approximates its fair value.

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The Company follows ASC 820, Fair Value Measurement, regarding fair value measurements which establishes a three-tier fair value hierarchy and prioritizes the inputs used in valuation techniques that measure fair value. These tiers include:

Level 1 — defined as observable inputs such as quoted prices for identical instruments in active markets;

Level 2 — defined as quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, or model-derived valuations for which all significant inputs are observable market data;

Level 3 — defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions.

Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company's assessment of the significance of an input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

The Company values its energy commodity swap contracts based on the applicable geographical market energy forward curve. The forward curves are derived based on the quotes provided by New York Mercantile Exchange, Amerex Energy Services and Tradition Energy. The Company does not consider that the pricing index used involves significant judgement on the part of management. Therefore, the Company classifies these commodity swap contracts within Level 2 of the valuation hierarchy based on the observable market rates used to determine fair value.

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 estimates the fair value of asset retirement obligations by calculating the estimated present value of the cost to retire the asset. This estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental, and political environments. In addition, the Company determines the Level 3 fair value measurements based on historical information and current market conditions. These assumptions represent Level 3 inputs, which can regularly change. As such, the fair value measurement of asset retirement obligations is subject to changes in these unobservable inputs as of the measurement date. The Company used a discounted cash flow model in which cash outflows estimated to retire the asset are discounted to their present value using an expected discount rate. A significant increase (decrease) in the discount rate in isolation could result in a significantly lower (higher) fair value measurement. The Company estimated the fair value of its asset retirement obligations based on discount rates ranging from 5.75% to 8.5%.

The Company accounted for the Convertible Note Payable at fair value at each reporting period. As of September 30, 2023, the Convertible Note Payable was repaid in full. As of December 31, 2022, the Company recorded the Convertible Note Payable at par plus accrued interest as it is payable on demand by either party and therefore represents fair value.

The fair value of the Sponsor Earnout Awards as of September 30, 2023 was determined using a Monte Carlo valuation model with a distribution of potential outcomes on a daily basis over the four-year post-close period. Assumptions used in the valuation are as follows:

• Current stock price — The Company's closing stock price of $8.20 as of September 30, 2023;

• Expected volatility —55% 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 — 4.72% 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 3.8 year term of the earnout period;

•Dividend yield - zero.

The fair value of the OPAL Earnout Awards as of September 30, 2023 was determined using a Monte Carlo valuation model with a distribution of potential outcomes for stock price and EBITDA over the 2-year period commencing on January 1, 2023 and ending on December 31, 2024. Assumptions used in the valuation are as follows:

• Current stock price — The Company's closing stock price of $8.20 as of September 30, 2023;

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•Weighted average cost of capital - 16% based on an average of historical volatilities of selected industry peers deemed to be comparable to our business.

•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 — 5.5% 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 1.5 year term of the earnout period;

•Dividend yield - zero.

There were no transfers of assets between Level 1, Level 2, or Level 3 of the fair value hierarchy as of September 30, 2023.

The Company's assets and liabilities that are measured at fair value on a recurring basis include the following as of September 30, 2023 and December 31, 2022, set forth by level, within the fair value hierarchy:

	Fair value as of September 30, 2023
	Level 1		Level 2		Level 3		Total
Liabilities:
Asset retirement obligation	$	—	$	—	$	6,563	$	6,563
Earnout liabilities	—		—		4,291		4,291
Assets:
Short term investments	18,028		—		—		18,028
Commodity swap contracts	—		603		—		603

	Fair value as of December 31, 2022
	Level 1		Level 2		Level 3		Total
Liabilities:
Asset retirement obligation	$	—	$	—	$	6,256	$	6,256
Convertible Note Payable (1)	—		28,528				28,528
Put option with Meteora	—		—		4,466		4,466
Commodity swap contracts	—		130		—		130
Earnout liabilities	—		—		8,790		8,790
Assets:
Short term investments	64,976		—		—		64,976
Swaption	—		182		—		182
Commodity swap contracts	—		954		—		954

(1) The fair value of the Convertible Note Payable as of December 31, 2022, represents the outstanding principal and paid-in-kind interest. Therefore it did not have any unobservable inputs which required the Company to develop its own assumptions. The methodology for calculating the fair value has changed as of December 31, 2022 as the prepayment penalty was cancelled upon consummation of Business Combination. Therefore, the Convertible Note Payable has been transferred from Level 3 to Level 2.

A summary of changes in the fair values of the Company’s Level 3 instruments, attributable to asset retirement obligations, for the nine months ended September 30, 2023 is included in Note 2, Summary of Significant Accounting Policies.

10. Related Parties

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

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Sale of Non-Controlling Interests to Related Parties

On November 29, 2021, as part of an exchange agreement, OPAL Fuels issued 14 newly authorized common units and 300,000 Series A-1 preferred units to Hillman in return for Hillman’s non-controlling interest in four RNG project subsidiaries for total consideration of $30,000. Upon the consummation of the Business Combination, the Series A-1 preferred units have been converted to Redeemable preferred non-controlling interests. The Company recorded paid-in-kind preferred dividends of $656 and $1,986 for the three and nine months ended September 30, 2023, respectively. The Company recorded paid-in-kind preferred dividends of $613 and $1,820 for the three and nine months ended September 30, 2022, respectively. The Company repaid all outstanding paid-in-kind preferred dividends as of September 30, 2023. Please see Note 13. Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Deficit, for additional information.

Issuance of Redeemable preferred non-controlling interests

On November 29, 2021, NextEra subscribed for up to 1,000,000 Series A preferred units, which are 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. The Company recorded paid-in-kind preferred dividends of $2,126 and $6,408 for the three and nine months ended September 30, 2023, respectively. The Company recorded paid-in-kind preferred dividends of $2,045 and $3,273 for the three and nine months ended September 30, 2022, respectively. The Company repaid all outstanding paid-in-kind preferred dividends as of September 30, 2023. Please see Note 13. Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' deficit, for additional information.

Purchase and Sale agreement for Environmental Attributes

On November 29, 2021, the Company entered into a Purchase and Sale agreement with NextEra for the Environmental Attributes generated by the RNG Fuels business. Under this agreement, the Company plans to sell a minimum of 90% of the Environmental Attributes generated and will receive net proceeds based on the agreed upon price less a specified discount. A specified volume of Environmental Attributes sold per quarter will incur a fee per Environmental Attribute in addition to the specified discount. The agreement was effective beginning January 1, 2022. For the three and nine months ended September 30, 2023, the Company earned net revenues after discount and fees of $25,724 and $43,784, respectively, under this contract which were recorded as part of Revenues - RNG fuel and Fuel Station Services. For the three and nine months ended September 30, 2022, the Company earned net revenues after discount and fees of $19,336 and $49,024, respectively, which were recorded as part of Revenues - RNG fuel and Fuel Station Services. Please see Note 2. Summary of Significant Accounting Policies for additional information.

Commodity Swap Contracts Under ISDA

The Company entered into an ISDA agreement with NextEra in November 2019. Pursuant to the agreement, the Company enters into commodity swap contracts on a periodic basis. As of September 30, 2023 and December 31, 2022, there were three commodity swap contracts outstanding. The Company records the realized and unrealized gain (loss) on these commodity swap contracts as part of Revenues - Renewable Power. Please see Note 9. Derivative Financial Instruments and Fair Value Measurements for additional information. The Company recorded $1,732 and $927 as revenues earned under the commodity swap contracts for the three months ended September 30, 2023 and 2022. The Company recorded $5,006 and $3,196 as revenues earned under the commodity swap contracts for the nine months ended September 30, 2023 and 2022.

Purchase Of Investments From Related Parties

In August 2021, the Company acquired 100% of the ownership interests in Reynolds, an RNG production facility for $12,020 which was funded with cash on hand. Reynolds held an equity investment of 1,570 Class B units in GREP representing 20% interest for a cash consideration of $1,570 which owns 50% of Biotown, a power generation facility under development to convert to an RNG facility. The Reynolds transaction was an asset acquisition from an affiliate under common control. The Company accounts for its 20% equity investment in GREP under the equity method. The Company recorded a net loss of $374 and net income of $3,034 as its share of net (loss) income for the three months ended September 30, 2023 and 2022, respectively. The Company recorded a net loss of $810 and net income of $2,478 as its share of net (loss) income for the nine months ended September 30, 2023 and 2022, respectively.

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Sales Contracts with Related Parties

In August 2020, Fuel Station Services contracted with Sunoma to dispense RNG and to generate and market the resulting RINs and LCFS credits created on behalf of the entity. Additionally, Fuel Station Services contracted with Pine Bend in December 2020 and Noble Road in March 2021 to provide the same services.

These contracts each have term of 10 years. The Company receives non-cash consideration in the form of RINs or LCFSs for providing these services and recognizes the RINs or LCFSs received as inventory based on their estimated fair value at contract inception. The Pine Bend and Noble road facilities came online in the first and third quarter of 2022. Sunoma came online in the fourth quarter of 2021. For the three months ended September 30, 2023 and 2022, the Company earned environmental processing fees of $570 and $80 net of intersegment elimination, which are included in Fuel Station Services revenues in the condensed consolidated statements of operations. For the nine months ended September 30, 2023 and 2022, the Company earned environmental processing fees of $1,711 and $322 net of intersegment elimination, which are included in Fuel Station Services revenues in the condensed consolidated statements of operations.

Service Agreements with Related Parties

On December 31, 2020, OPAL Fuels signed a Management, Operations, and Maintenance Services Agreement (“Administrative Services Agreement”) with Fortistar LLC ("Fortistar"), pursuant to which Fortistar provides management, operations, and maintenance services to the Company. The Administrative Services Agreement expires on December 31, 2023, unless termination occurs earlier due to dissolution of the Company or it is terminated by the Company’s secured lenders in certain circumstances. The Administrative Services Agreement provides for payment of service fees based on actual time incurred at contractually agreed rates, as well as a fixed annual payment of $580 per year adjusted annually for inflation. Additionally, the Administrative Services Agreement provides for the Company to receive credits for any services provided by the Company's employees to Fortistar. For the three and nine months ended September 30, 2023 and 2022, there have been no material services provided by the Company's employees to Fortistar.

In June 2021, the company entered into a Management Services Agreement with Costar Partners LLC (“Costar”), an affiliate of Fortistar. Pursuant to the Management Services Agreement, Costar provides information technology (“IT”) support services, software use, licensing services, management of third party infrastructure and security services and additional IT services as needed by the Company. The Management Services Agreement provides for Costar to be compensated based on actual costs incurred and licensing fees per user for certain software applications. The Management Services Agreement expires in June 2024 unless the termination occurs earlier due to dissolution of the Company or it is terminated by the Company’s secured lenders in certain circumstances.

The following table summarizes the various fees recorded under the agreements described above which are included in "Selling, general, and administrative" expenses:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Staffing and management services	$	414	$	578	$	1,406	$	1,683
Rent - fixed compensation	166		168		494		442
IT services	754		636		2,210		1,721
Total	$	1,334	$	1,382	$	4,110	$	3,846

As of September 30, 2023 and December 31, 2022, the Company had Accounts payable, related party in the amounts of $1,365 and $1,346, respectively.

11. Reportable Segments and Geographic Information

The Company is organized into four operating segments based on the characteristics of its renewable power generation, dispensing portfolio, and the nature of other products and services. During the first quarter of 2023, the Company changed its internal reporting to its Chief Operating Decision Makers to change the composition of revenues

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included in our reportable segments. The internal reporting was changed to provide more visibility into our RNG fuel production and operations and to align fuel dispensing revenues with construction and service of fuel dispensing stations. Additionally, the Company changed its internal reporting to report revenues from RECs and ISCC Carbon Credits from RNG Fuel to Renewable Power segment in the current quarter. This is primarily to reflect a strategic business change to identify all revenues earned from environmental attributes generated from Renewable Power facilities in the same segment.

Therefore, the Company reclassified the revenues and the corresponding cost of sales for CNG tolling business which were previously presented as part of Revenues - RNG Fuel and Cost of sales - RNG Fuel to Revenues - Fuel station services and Cost of sales - Fuel station services, respectively. The Company reclassified revenues earned from sale of RECs and ISCC Carbon Credits from Revenues - RNG Fuel to Revenues - Renewable Power. The Company also adjusted the revenues and cost of sales for the prior year period presented for comparison purposes.

For the three months ended September 30, 2023 and 2022, the Company classified revenues from its fuel dispensing business of $16,852 and $12,545, respectively, as part of Revenues - Fuel station services. For the nine months ended September 30, 2023, the Company classified revenues from fuel dispensing business of $35,103 and $31,852, respectively, as part of Revenues - Fuel station services.

For the three months ended September 30, 2023 and 2022, the Company classified revenues from the sale of environmental attributes generated from Renewable Power facilities of $4,539 and $1,543, respectively, as part of Revenues - Renewable Power. For the nine months ended September 30, 2023 and 2022, the Company classified revenues from the sale of environmental attributes generated from Renewable Power facilities of $15,783 and $2,528, respectively, as part of Revenues - Renewable Power.

For the three months ended September 30, 2023 and 2022, the Company classified cost of sales related to fuel dispensing business of $11,703 and $10,088, respectively as part of Cost of sales - Fuel station services. For the nine months ended September 30, 2023 and 2022, the Company classified cost of sales related to the fuel dispensing business of $28,527 and $24,801, respectively as part of Cost of sales - Fuel station services.

We aligned our reportable segments disclosure to align with the information and internal reporting that is provided to our Chief Operating Decision Makers. Therefore, the Company reassessed its reportable segments and revised all the prior periods to make the segment disclosures comparable.

•RNG Fuel. The RNG Fuel segment relates to all RNG supply directly related to the generation and sale of brown gas and environmental credits, and consists of:

◦Development and construction – RNG facilities in which long term gas right contracts have been, or are in the process of being ratified and the construction of RNG generation facilities.

◦RNG supply operating facilities – This includes the generation, extraction, and sale of RNG - plus associated RINs and LCFSs from landfills.

For the three and nine months ended September 30, 2023 and 2022, the Company has accounted for its interests in Pine Bend, Reynolds and Noble Road under the equity method of accounting and the results of operations of Beacon, New River, Central Valley and Sunoma were consolidated in its condensed consolidated statement of operations. As of May 30, 2023, the Company deconsolidated Emerald and Sapphire. As a result, the Company consolidated Emerald and Sapphire for the period between January 1, 2023 and May 30, 2023 and recorded its ownership interests in Paragon which includes Emerald and Sapphire as equity method investment for the period between May 30, 2023 and September 30, 2023.

As of September 30, 2023, Central Valley, and Sapphire are not operational. Sunoma became operational in December 2021, Noble Road in January 2022, New River in April 2022 and Pine Bend in September 2022. Emerald began commercial operations in the third quarter of 2023.

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

◦Service and maintenance contracts for RNG/CNG fueling sites and a manufacturing division that builds Compact Fueling Systems and Defueling systems.

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◦Third Party CNG Construction of Fueling Stations - design/build and serve as general contractor for typically Guarantee Maximum Price or fixed priced contracts for customers usually lasting less than one year.

◦RNG and CNG fuel dispensing stations for vehicle fleets - This includes both the dispensing and sale of brown gas and the environmental credit generation and monetization. The Company operates Fueling Stations that dispense gas for vehicles. This also includes the development and construction of these facilities.

•Renewable Power Portfolio. The Renewable Power portfolio segment generates renewable power through methane-rich landfills which is then sold to public utilities throughout the United States. The Renewable Power portfolio operates primarily in Southern California.

•Corporate. This segment consists of activities managed and maintained at the Company corporate level primarily including but not limited to:

◦Executive, accounting, finance, sales activities such as: payroll, stock compensation expense, travel and other related costs.

◦Insurance, professional fees (audit, tax, legal etc.).

The Company has determined that each of the four operating segments meets the characteristics of a reportable segment under U.S. GAAP. The Company's activities and assets that are not associated with the four reportable segments are summarized in the "Other" category below. These include corporate investment income, interest income and interest expense, income tax expense, and other non-allocated costs.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Revenues:
Renewable Power	$	13,708	$	49,737	$	43,543	$	70,937
RNG Fuel	29,551		22,788		61,395		61,971
Fuel Station Services	40,326		39,333		99,056		91,325
Intersegment	(3,021)		(3,150)		(10,967)		(8,172)
Equity Method Investment(s)	(9,463)		(42,158)		(23,927)		(47,247)
	$	71,101	$	66,550	$	169,100	$	168,814

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Interest and Financing Expense, Net:
Renewable Power	$	(2)	$	(1,440)	$	(260)	$	(3,559)
RNG Fuel	(3,243)		(189)		(4,616)		(240)
Fuel Station Services	27		(14)		120		(28)
Corporate	333		853		274		(3,385)
	$	(2,885)	$	(790)	$	(4,482)	$	(7,212)

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	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Depreciation, Amortization, and Accretion:
Renewable Power	$	1,488	$	1,176	$	4,389	$	4,283
RNG Fuel	2,492		2,461		6,808		6,379
Fuel Station Services	917		411		2,555		616
Other(1)	9		31		36		95
Equity Method Investment(s)	(1,167)		(699)		(2,854)		(1,272)
	$	3,739	$	3,380	$	10,934	$	10,101

(1)Other includes amortization of intangible assets and depreciation expense not allocated to any segment.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Net income (loss)
Renewable Power	$	983	$	3,483	$	10,584	$	1,314
RNG Fuel	10,821		5,669		8,044		21,775
Fuel Station Services	5,530		11,624		7,429		12,574
Corporate	(18,833)		(19,101)		79,441		(38,761)
Equity Method Investment(s)	1,726		3,694		1,433		3,658
	$	227	$	5,369	$	106,931	$	560

	Nine Months Ended September 30,
	2023		2022
Cash paid for Purchases of Property, Plant, and Equipment:
Renewable Power	$	—	$	1,800
Fuel Station Services	16,860		7,038
RNG Fuel	75,390		76,496
	$	92,250	$	85,334

	September 30, 2023		December 31, 2022
Total Assets:
Renewable Power	$	39,503	$	43,468
RNG Fuel	290,247		347,750
Fuel Station Services	131,838		119,669
Corporate	29,401		82,204
Equity Method Investment(s)	199,466		51,765
	$	690,455	$	644,856

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

12. Variable Interest Entities

We determine whether we are the primary beneficiary of a VIE upon our initial involvement with the VIE and we reassess whether we are the primary beneficiary of a VIE on an ongoing basis. Our determination of whether we are the primary beneficiary of a VIE is based upon the facts and circumstances for each VIE and requires judgment. Our considerations in determining the VIE's most significant activities and whether we have power to direct those activities

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include, but are not limited to, the VIE's purpose and design and the risks passed through to investors, the voting interests of the VIE, management, service and/or other agreements of the VIE, involvement in the VIE's initial design, and the existence of explicit or implicit financial guarantees. If we are the party with the power over the most significant activities, we meet the "power" criteria of the primary beneficiary. If we do not have the power over the most significant activities or we determine that all significant decisions require consent of a third party, we do not meet the "power" criteria of the primary beneficiary.

We assess our variable interests in a VIE both individually and in aggregate to determine whether we have an obligation to absorb losses of or a right to receive benefits from the VIE that could potentially be significant to the VIE. The determination of whether our variable interest is significant to the VIE requires judgment. In determining the significance of our variable interest, we consider the terms, characteristics and size of the variable interests, the design and characteristics of the VIE, our involvement in the VIE, and our market-making activities related to the variable interests.

As of September 30, 2023, the Company held equity interests in seven VIEs — Sunoma, GREP, Emerald, Sapphire, Paragon, SJI Joint Venture (RNG Atlantic and RNG Burlington) and Central Valley. On May 30, 2023, the Company together with a third-party environmental solutions company formed Paragon. The Company owns 50% of ownership interest in Paragon. Concurrent with the formation of Paragon, the Company contributed its 50% ownership interests in Emerald and Sapphire to Paragon.

Upon the execution of the above the transaction, the Company reassessed its equity interests in Emerald and Sapphire under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in Paragon under ASC 810 because the governance of the joint venture is driven by an independent board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of Paragon.

Based on the above analysis, the Company determined that it should account for its ownership interests in Paragon under the equity method of accounting pursuant to ASC 323, Investments Equity Method and Joint Ventures, prospectively, as the Company has the ability to exercise significant influence, but not control over the joint venture company.

Prior to May 30, 2023, the Company consolidated these two entities in accordance with the variable interest entity model guidance under ASC 810, Consolidation.

On September 14, 2023, OPAL L2G, a wholly-owned indirect subsidiary of the Company, entered into the Agreement with SJI LRNG, a wholly-owned indirect subsidiary of SJI, establishing the terms and conditions of governance and operation of the SJI Joint Venture. The purpose of the SJI Joint Venture, which is owned 50/50 by OPAL L2G and SJI LRNG, is to develop, construct, own and operate Facilities to produce RNG using biogas generated by certain landfills.

Upon the execution of the above transaction, the Company reassessed its equity interests in the SJI Joint Venture under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in SJI Joint Venture under ASC 810 because the governance of the joint venture is driven by a board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of SJI Joint Venture. As of September 30, 2023, there have been no material contribution made by the Company in the SJI Joint Venture.

As of September 30, 2023, GREP and Paragon were presented as equity method investments and the remaining two VIEs Sunoma and Central Valley are consolidated by the Company.

At December 31, 2022, GREP has been presented as an equity method investment and the remaining four VIEs Sunoma, Emerald, Sapphire, and Central Valley are consolidated by the Company.

In 2020, the Company acquired a variable interest in Sunoma in a joint venture with a third-party who does not have any equity at risk but participates in proportionate share of income or losses, which may be significant. Additionally, the assets in Sunoma are collateralized under the Sunoma loan, the proceeds of which are used for partial financing of the construction of the Sunoma facility. Therefore, the significant assets and liabilities of Sunoma are parenthesized in the condensed consolidated balance sheets as of September 30, 2023 and December 31, 2022.

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The Company determined that each of these entities are VIEs and in its capacity as a managing member except for Emerald and Sapphire, the Company is the primary beneficiary. The Company is deemed as a primary beneficiary based on two conditions:

•The Company, as a managing member, has the power to order the activities that significantly impact the economic performance of the two entities including establishment of strategic, operating, and capital decisions for each of these entities; and

•The Company has the obligation to absorb the potential losses for the right to receive potential benefits, which could be significant to the VIE;

As a primary beneficiary, the Company consolidates these entities in accordance with the variable interest entity model guidance under ASC 810, Consolidation.

Our variable interests in each of our VIEs arise primarily from our ownership of membership interests, construction commitments, our provision of operating and maintenance services, and our provision of environmental credit processing services to VIEs.

The following table summarizes the major condensed consolidated balance sheet items for consolidated VIEs as of September 30, 2023 and December 31, 2022. The information below 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 amount of assets that can only be used to settle obligations of the VIEs are parenthesized in the condensed consolidated balance sheets and are included in the asset totals listed in the table below.

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	As of September 30, 2023		As of December 31, 2022
Assets
Current assets:
Cash and cash equivalents	$	1,302	$	12,506
Accounts receivable, net	79		966
Restricted cash - current	1,232		6,971
Environmental credits held for sale	29		—
Prepaid expenses and other current assets	193		415
Total current assets	2,835		20,858
Property, plant and equipment, net	26,684		73,140
Restricted cash, non-current	2,843		2,923
Total assets	$	32,362	$	96,921
Liabilities and equity
Current liabilities:
Accounts payable	$	603	$	4,896
Accounts payable, related party	1,035		433
Accrued capital expenses	—		7,821
Accrued expenses	602		646
Sunoma Loan- current portion	1,739		380
Total current liabilities	3,979		14,176
Sunoma loan, net of debt issuance costs	20,402		21,712
Total liabilities	24,381		35,888
Equity
Stockholders' equity	7,097		34,588
Non-redeemable non-controlling interests	884		26,445
Total equity	7,981		61,033
Total Liabilities and Equity	$	32,362	$	96,921

13. Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Deficit

Common stock

As of September 30, 2023, there are (i) 29,332,333 shares of Class A common stock issued and outstanding, (ii) 144,399,037 shares of New OPAL Class D common stock issued and outstanding, (iii) no shares of Class B common stock, par value $0.0001 per share, 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) and (iv) no shares of Class C common stock, par value $0.0001 per share, (“ Class C common stock”) issued and outstanding (shares of Class D common stock do not have any economic value except voting rights as described below)

During the first quarter of 2023, Meteora exercised the put option pursuant to the terms of the Forward Purchase Contract. The Company repurchased 1,635,783 shares at a price of $10.02 per share. The Company recorded $11,614 representing the fair value of the treasury stock as part of stockholders' deficit and $4,777 as an offset to the derivative financial liability, current on its condensed consolidated balance sheet as of September 30, 2023.

In March 2023, the Company issued 49,633 shares to certain warrant holders as consideration for their prior agreement to tender all warrants held by the warrant holders in the Company's voluntary exchange offer which closed on December

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22, 2022. The Company recorded $338 representing the fair value of the shares issued based on the closing price on March 30, 2023 as part of Other income (expense), net.

Redeemable preferred non-controlling interests

On November 29, 2021, as part of an Exchange Agreement, the Company issued 300,000 Series A-1 preferred units to Hillman in return for Hillman’s non-controlling interest in four RNG project subsidiaries.

On November 29, 2021, NextEra subscribed for up to 1,000,000 Series A preferred units, which are 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.

Upon completion of the Business Combination, the Company assumed Series A-1 preferred units and Series A preferred units which were issued and outstanding by OPAL Fuels. The Company recorded the Series A-1 preferred units and Series A preferred units as Redeemable preferred non-controlling interests. The Company has elected to adjust the carrying value of the preferred units to the redemption value at the end of each reporting period by immediately amortizing the issuance costs in the first reporting period after issuance of the preferred units.

During the third quarter of 2023, the Company repaid all outstanding paid-in-kind preferred dividends.

The following table summarizes the changes in the redeemable preferred non-controlling interests which represent Series A and Series A-1 preferred units outstanding at OPAL Fuels level from December 31, 2022 to September 30, 2023:

	Series A-1 preferred units			Series A preferred units
	Units	Amount		Units	Amount		Total
Balance, December 31, 2022	300,000	$	32,736	1,000,000	$	105,406	$	138,142
Series A units issued by OPAL Fuels	—	—		—	—		—
Paid-in-kind dividends attributable to OPAL Fuels	—	320		—	1,032		1,352
Paid-in kind dividends attributable to Class A common stockholders	—	1,666		—	5,376		7,042
Repayment of paid-in-kind preferred dividends	—	(4,722)		—	$	(11,814)	(16,536)
Balance, September 30, 2023	300,000	$	30,000	1,000,000	$	100,000	$	130,000

Terms of Redeemable Preferred Units

The Series A and Series A-1 preferred units (together the “Preferred Units”) are subject to substantially the same terms and features which are listed below:

Voting: The Series A-1 preferred units to Hillman do not have any voting rights. The Series A preferred units issued to NextEra have limited rights to prevent the Company 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 dispositions of assets and (iv) major acquisitions of assets outside of the Company’s primary business.

Dividends: The 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 is allowed to elect to issue additional Preferred Units ( paid-in-kind) in lieu of cash for the first eight dividend payment dates. The Company elected to pay the dividends to be paid-in-kind for all periods presented. The annual dividend rate increases to 12% if certain events of defaults occur. Additionally, the dividend rate increases by 2% for each unrelated uncured event of default up to a maximum of 20%.

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

Redemption: Any time after issuance, the Company may redeem the Redeemable preferred units for a price equal to original issue price of $100 per unit plus any accrued and unpaid dividends. Holders of the Preferred Units may redeem for an amount equal to original issue price of $100 per unit plus any accrued and unpaid dividends (i) upon the occurrence of certain change in control event (ii) at the end of four years from the date of issuance, except that the Preferred Units issued to Hillman can only be redeemed 30 days after the fourth year anniversary of the first issuance of Preferred Units to NextEra. The maturity date is determined to be the date at which the Holder’s redemption option becomes exercisable as this is the date on which both the Company and the Holder may redeem the Preferred Units. The maturity date may be as early as November 29, 2025 but shall not occur later than June 30, 2026.

Conversion: Holders may elect to convert Preferred Units into common units in the event that the Company fails to redeem the Preferred Units under an optional redemption. The annual dividend rate shall increase to 12% and will further increase to 14% after one year, and thereafter by 2% every 90 days up to a maximum of 20%. The Company must also redeem all NextEra Series A preferred units on which the redemption option has been exercised prior to redeeming any Hillman Series A-1 preferred units. If elected, the Holder may convert all or a portion of its Preferred Units into a number of common units equal to the number of Preferred Units, multiplied by$100, plus accrued and unpaid cash dividends, divided by the conversion price. The conversion price is equal to the value of the Company’s common units determined as follows, and reduced by (i) a 20% discount if conversion occurs during the first year of delayed redemption, (ii) a 25% discount during the 2nd year, and (iii) a 30% discount thereafter:

1. Using 20-day volume-weighted average price (“VWAP”) of the Company's common shares.

2. Otherwise the estimated proceeds to be received by the Holder of a common unit if the net assets of the Company were sold at fair market value and distributed.

Redeemable non-controlling interests

Upon consummation of the Business Combination, OPAL Fuels and its members caused the existing Limited Liability Company Agreement to be amended and restated. In connection therewith, all of the common units of OPAL Fuels issued and outstanding immediately prior to the Business Combination were re-classified into 144,399,037 Class B Units. Each Class B Unit is paired with a single non-economic share of Class D common stock issued by the Company. Each pair of Class B Unit and a single share of Class D common stock is exchangeable to either a single share of Class A common stock or a single share of Class C common stock at the holder's option. Upon an exchange for Class A common stock, the Company has the option to redeem shares for cash at their market value.

Redeemable non-controlling interests have been presented as mezzanine equity in the condensed consolidated statements of change in Redeemable non-controlling interests, Redeemable preferred non-controlling interests and stockholders' equity. At each balance sheet date, the Redeemable non-controlling interests are adjusted up to their redemption value if necessary, with an offset in Stockholders' equity. As of September 30, 2023, the Company recorded $1,158,937 to adjust the carrying value to their redemption value based on a five-day VWAP of $8.03 per share.

14. Stock-based compensation

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

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On March 31, 2023, the Company issued 196,961 stock options, 888,831 restricted stock units and 274,617 performance units to certain employees of the Company. The fair value of the stock options was determined to be $5.26 based on Black Scholes model based on the share price of $6.97, exercise price of $6.97, expiration of 10 years, annual risk free interest rate of 4.04% and volatility of 65%. Additionally, the Company issued 135,583 restricted stock units to the board of directors. The total fair value of the equity awards was $6,955.

A summary of the equity awards under the 2022 Plan for the nine months ended September 30, 2023 is as follows:

	Number of Units outstanding	Weighted Average Grant Date Fair Value		Aggregate Fair Value (in thousands)
Restricted Stock Units:
Unvested awards as of December 31, 2022	422,349	$	7.94
Granted	1,038,347	6.98
Vested in August 2023	(2,135)	6.97
Shares withheld for settlement of taxes	(1,046)
Forfeitures	(50,378)	7.49
Restricted Stock Units outstanding as of September 30, 2023	1,407,137	$	7.31	$	10,284
Stock Options:
Unvested awards as of December 31, 2022	—	—
Granted	196,961	$	5.26
Stock Options outstanding as of September 30, 2023	196,961	$	5.26	$	1,036
Performance Stock Units:
Unvested awards as of December 31, 2022	—
Granted	274,617	$	6.97
Vested in August 2023	(83)
Shares withheld for settlement of taxes	(31)
Forfeitures	(3,975)	$	6.97
Performance Stock Units outstanding as of September 30, 2023	270,528	$	6.97	$	1,553
Total unvested awards outstanding as of September 30, 2023	1,874,626	$	6.87	$	12,873

Stock-based compensation expense for all stock awards included in Selling, general and administrative expenses:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Stock-based compensation expense	$	1,899	$	160	$	4,747	$	320
	$	1,899	$	160	$	4,747	$	320

Stock-based compensation expense related to unvested awards yet to be recognized as of September 30, 2023 totaled $7,705 and is expected to be recognized, on a weighted average basis, over 2.3 years.

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15. Net (Loss) Income Per Share

The basic income per share of Class A common stock is computed by dividing the net (loss) income attributable to Class A common stockholders by the weighted average number of Class A common stock outstanding during the period. The basic income per share for the three and nine months ended September 30, 2023 does not include 1,635,783 shares in treasury, 763,908 shares issued and outstanding but are contingent on achieving earnout targets. In the first quarter of 2023, the put option was exercised and 197,258 shares of Class A common stock were cancelled.

The diluted income per share of Class A common stock for the three and nine months ended September 30, 2023 does not include Redeemable preferred non-controlling interests because the substantive contingency for conversion has not been met as of September 30, 2023. It does not include 144,399,037 OPAL Fuels Class B units representing Redeemable non-controlling interest as its impact is anti-dilutive. It does not include 763,908 Sponsor Earnout Awards and 10,000,000 OPAL Earnout Awards as their target share price and adjusted EBITDA contingencies have not been met as of September 30, 2023. The outstanding stock options issued under the 2022 Plan are not included as their impact is antidilutive. The outstanding performance units under the 2022 Plan are not included as the performance conditions have not been met as of September 30, 2023.

The Class D common stock does not participate in the earnings or losses of the Company and are therefore not participating securities. As such, separate presentation of basic and diluted earnings per share of Class D common stock under the two-class method has not been presented.

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

	Three Months Ended		Nine Months Ended
	September 30, 2023		September 30, 2023
Net (loss) income attributable to Class A common stockholders	(400)		$	15,945
Weighted average number of shares of Class A common stock - basic	26,978,969		27,110,953
Dilutive effect of stock options, restricted stock units, performance units, Convertible note payable, earnout shares, Redeemable preferred non-controlling interests, Redeemable non-controlling interests	—		572,902
Weighted average number of shares of Class A common stock - diluted	26,978,969		27,683,855
Net loss per share of Class A common stock
Basic	$	(0.01)	$	0.59
Diluted	$	(0.01)	$	0.58

16. Income Taxes

As a result of the Company’s up-C structure effective with the Business Combination, the Company expects to be a tax-paying entity. However, as the Company has historically been loss-making, any deferred tax assets created as a result of net operating losses and other deferred tax assets for the excess of tax basis in the Company's investment in Opal Fuels would be offset by a full valuation allowance. Prior to the Business Combination, OPAL Fuels was organized as a limited liability company, with the exception of one partially-owned subsidiary which filed income tax returns as a C-Corporation. The Company accounts for its income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to the differences between the financial statement carrying amount of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in earnings in the period that includes the enactment date. Judgment is required in determining the provisions for income and other taxes and related accruals, and deferred tax assets and liabilities. In the ordinary course of

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business, there may be transactions and calculations where the ultimate tax outcome is uncertain. Additionally, the Company's various tax returns are subject to audit by various tax authorities. Although the Company believes that its estimates are reasonable, actual results could differ from these estimates.

For the three and nine months ended September 30, 2023, the Company recorded zero income tax expense. The effective tax rate for the three and nine months ended September 30, 2023 was 0%. The difference between the Company’s effective tax rate for the three and nine months ended September 30, 2023 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 did not record a tax provision for the three and nine months ended September 30, 2022 primarily due to OPAL Fuels' status as a pass-through entity for U.S. federal income tax purposes. 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.

17. Commitments and Contingencies

Letters of Credit

As of September 30, 2023 and December 31, 2022, the Company was required to maintain five and nine standby letters of credit totaling $10,498 and $2,292, respectively, to support obligations of certain Company 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.

Purchase Options

The Company has two contracts with customers to provide CNG for periods of seven and ten years, respectively. The customers have an option to terminate the contracts and purchase the Company's CNG Fueling Station at the customers' sites for a fixed amount that declines annually.

In July 2015, the Company entered into a ten year Fuel Sales Agreement with a customer that included the construction of a CNG Fueling Station owned and managed by the Company on the customer's premises. At the end of the contract term, the customer has an option to purchase the CNG Fueling Station for a fixed amount. The cost of the CNG Fueling Station was recorded to Property, plant, and equipment and is being depreciated over the contract term.

On May 30, 2023, OPAL Intermediate Holdco 2 assigned to Paragon its rights and obligations under the OPAL Term Loan II. Additionally, the Company signed an equity commitment letter up to a maximum of $2,100, to Paragon relating to its share of equity contribution towards any cost over runs in connection with the construction and completion of Emerald project.

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.

In September 2021, an indirect subsidiary of the Company, MD Digester, LLC entered into a fixed-price Engineering, Procurement and Construction Contract (an “EPC Contract”) with VEC Partners, Inc. dba 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 entered into a nearly identical EPC Contract for the design and construction of a second facility, also in California’s Central Valley. CEI’s performance under both of the EPC Contracts is fully bonded by licensed sureties.

CEI has submitted a series of change order requests seeking to increase the EPC Contract Price by approximately $14 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 termination (for default) of one of CEI’s major equipment manufacturers. The Company disputes the vast majority of the change order requests. The Company, CEI and CEI’s surety are in active settlement discussions and have agreed to a temporary funding arrangement pending resolution of the disputed change

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orders to keep the projects moving forward. No formal legal proceedings have been filed, and no discovery has been performed.

18. Subsequent Events

On October 5, 2023, Ms. Ann Anthony gave notice of her intention to resign as Chief Financial Officer ("CFO") of the Company to pursue another professional opportunity. Ms. Anthony’s departure date was at the time not yet determined. Ms. Anthony will, also resign from her positions as the Company’s Principal Financial Officer and Principal Accounting Officer. On October 10, 2023, the board of directors of the Company appointed Mr. Scott Contino as Interim Chief Financial Officer. Mr. Contino will assist Ms. Anthony during the transition and assume the CFO role on the date of Ms. Anthony’s departure. The Company has entered into an interim services agreement (the “Interim Services Agreement”) with Fortistar in accordance with the terms and conditions of the existing Administrative Services Agreement between the Company and Fortistar. Pursuant to the Interim Services Agreement, the Company will pay Fortistar a services fee as described below, which is substantially the same as the cash compensation that was paid to Ms. Anthony.

On October 19, 2023, Ms. Anthony signed a separation agreement with the Company, pursuant to which Ms. Anthony has agreed to serve in her current role until November 15, 2023. Certain equity incentive awards that were granted to Ms. Anthony, and that would have otherwise been forfeited due to her resignation, will vest on March 31, 2024 in accordance with the Separation Agreement. These equity awards consist of 33,328 restricted stock units and options to purchase 5,545 shares of Class A Common Stock at an exercise price of $6.97.

On October 20, 2023 (the “Effective Date”), a wholly-owned subsidiary of the Company entered into an Asset Purchase and Sale Agreement (for the purposes of this paragraph, the “Agreement”) with Washington Gas Light Company ("WGL"). The subsidiary is currently constructing a production facility (the “Facility”) at the Prince William County landfill located in Manassas, Virginia, on a parcel located on the landfill, to process landfill gas into RNG. The Agreement obligates the subsidiary to develop, plan and permit a gas pipeline extension and associated interconnection facilities (the “Project”) to deliver RNG from the Facility to an interconnection point on WGL’s pipeline. Per the terms and conditions of the Agreement, WGL will purchase the Project from the subsidiary after the final completion of same at a purchase price of $25 million. The closing is contingent upon approval of the Agreement by the Virginia State Corporation Commission, as well as the satisfaction of customary closing conditions, and the outside closing date is on or prior to the 12-month anniversary of the Effective Date.

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

In this 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 the Company's unaudited condensed consolidated financial statements as of September 30, 2023 and for the three and nine months ended September 30, 2023 and 2022, and the audited consolidated financial statements and notes thereto included in the Company's Annual Report. 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

We are a renewable energy company specializing in the capture and conversion of biogas for the (i) production of RNG for use as a vehicle fuel for heavy and medium-duty trucking fleets, (ii) generation of electricity generated from renewable sources ("Renewable Power") for sale to utilities, (iii) generation and sale of Environmental Attributes (as defined below) associated with RNG and Renewable Power, and (iv) sales of RNG as pipeline quality natural gas. 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. The Biogas Conversion Projects currently use LFG and dairy manure as the source of the biogas. 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. The term “Environmental Attributes” refers to federal, state and local government incentives in the United States, provided in the form of RINs, RECs, LCFS credits, ISCC Carbon Credits, rebates, tax credits and other incentives to end users, distributors, system integrators and manufacturers of renewable energy projects.

Recent developments

On October 5, 2023, Ms. Ann Anthony gave notice of her intention to resign as Chief Financial Officer ("CFO") of the Company to pursue another professional opportunity. Ms. Anthony’s departure date was at the time not yet determined. Ms. Anthony will, also resign from her positions as the Company’s Principal Financial Officer and Principal Accounting Officer. On October 10, 2023, the board of directors of the Company appointed Mr. Scott Contino as Interim Chief Financial Officer. Mr. Contino will assist Ms. Anthony during the transition and assume the CFO role on the date of Ms. Anthony’s departure. The Company has entered into an interim services agreement (the “Interim Services Agreement”) with Fortistar in accordance with the terms and conditions of the existing Administrative Services Agreement between the Company and Fortistar. Pursuant to the Interim Services Agreement, the Company will pay Fortistar a services fee as described below, which is substantially the same as the cash compensation that was paid to Ms. Anthony.

On October 19, 2023, Ms. Anthony signed a separation agreement with the Company, pursuant to which Ms. Anthony has agreed to serve in her current role until November 15, 2023. Certain equity incentive awards that were granted to Ms. Anthony, and that would have otherwise been forfeited due to her resignation, will vest on March 31, 2024 in accordance with the Separation Agreement. These equity awards consist of 33,328 restricted stock units and options to purchase 5,545 shares of Class A Common Stock at an exercise price of $6.97.

On October 20, 2023 (the “Effective Date”), a wholly-owned subsidiary of the Company entered into an Asset Purchase and Sale Agreement (for the purposes of this paragraph, the “Agreement”) with Washington Gas Light Company ("WGL"). The subsidiary is currently constructing a production facility (the “Facility”) at the Prince William County landfill located in Manassas, Virginia, on a parcel located on the landfill, to process LFG into RNG. The Agreement obligates the subsidiary to develop, plan and permit a gas pipeline extension and associated interconnection facilities (the “Project”) to deliver RNG from the Facility to an interconnection point on WGL’s pipeline. Per the terms and conditions of the Agreement, WGL will purchase the Project from the subsidiary after the final completion of same at a purchase price of $25 million. The closing is contingent upon approval of the Agreement by the Virginia State Corporation Commission, as well as the satisfaction of customary closing conditions, and the outside closing date is on or prior to the 12-month anniversary of the Effective Date.

Impact of COVID-19

In response to the COVID-19 pandemic, we instituted a safety committee to oversee our compliance with federal, state, and local government mandates, and ensure that the Company adheres to Centers for Disease Control guidelines to maintain safe working conditions for our employees. Some of the protocols we implemented include limiting in-person work to essential personnel and performing temperature checks. Since March 2020, where practicable, our employees have

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worked remotely and minimized travel and other non-essential contact. Additionally, we are providing our employees with COVID-19 testing at no cost and personal protective equipment for their safety and well-being.

As of the date of this report, the COVID-19 pandemic has had a relatively minimal economic impact on our results of operations.

The duration and future economic severity of the COVID-19 remains uncertain, and our results of operations and financial condition could potentially face material adverse effect(s) in the future due to COVID-19.

Critical Accounting Policies

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 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 judgments that affect the reported amounts of assets and liabilities, revenues, expenses and warrants 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. As the discussion and analysis of our financial condition and results of operations are based upon our interim unaudited condensed consolidated financial statements, they do not include all of the information on critical accounting policies normally included in consolidated financial statements. Accordingly, a detailed description of these critical accounting policies and the consolidated financial statements and notes thereto are included in the Company’s Annual Report.

Use of Estimates

The preparation of the 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, disclosure of contingent assets and liabilities at the date of the condensed consolidated financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The significant estimates and assumptions of the Company relate to the useful lives of property, plant and equipment, fair value of the deconsolidated VIEs, the value of stock-based compensation and the fair value of derivatives including warrant liabilities, earnout liabilities, put option on a forward purchase agreement, interest rate swaps and commodity swap contracts.

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, and access to suitable biogas production resources. 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 (cellulosic biofuel with a 60% greenhouse gas (“GHG”) reduction requirement) 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 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 CO₂ and other climate-harming GHG emissions in the United States, and transitioning this sector to low and negative carbon fuels is a critical step

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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 ISCC Carbon Credits and RECs. ISCC Carbon Credits and 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 ISCC Carbon Credits 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, associated ISCC Carbon Credits and 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.

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 statement 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

◦The Company's interests in both operating and construction projects.

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

◦Manufacturing division that builds Compact Fueling Systems and Defueling systems;

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

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

◦RNG and CNG Fuel Dispensing Stations - This includes both the dispensing (or sale) of RNG, commodity natural gas, and environmental credit generation and monetization. The Company operates Fueling Stations that dispense both CNG and RNG fuel for vehicles.

•Renewable Power Portfolio. The Renewable Power portfolio segment generates renewable power and associated environmental attributes such as ISCC Carbon Credits and 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.

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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.

Results of Operations for the three and nine months ended September 30, 2023 and 2022:

Operational Results

The following table summarizes the operational data achieved for the three and nine months ended September 30, 2023 and 2022:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
RNG Fuel Capacity and Utilization
Design Capacity (Million MMBtus)(1)	1.3		1.0		3.9		2.9
Volume of Inlet Gas (Million MMBtus)	0.8		0.7		2.2		1.7
Inlet Design Capacity Utilization % (2) (3)	79	%	78	%	77	%	72	%
RNG Fuel volume produced (Million MMBtus)	0.7		0.6		2.0		1.5
Utilization of Inlet Gas % (3) (4)	84	%	85	%	85	%	87	%

(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 weighted average of Volume of Inlet Gas, divided by the total Design Capacity. 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.

(3) Data not available for the Company's dairy projects, i.e., Sunoma and Biotown.

(4) Utilization of Inlet Gas is measured as weighted average of RNG Fuel Produced divided by 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% - 90%.

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	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Renewable Power
Design Capacity (MW per hour)(1)	83.6		112.5		102.8		112.5
Design Capacity for the period (Millions MWh) (1)	0.25		0.25		0.73		0.73
Renewable Power produced ( Millions MWh)	0.11		0.11		0.35		0.37
Design Capacity Utilization (%) (2)	44	%	44	%	48	%	51	%

(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%.

RNG Projects

Below is a table setting forth the RNG projects in operation and construction in our portfolio:

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	OPAL's Share of Design Capacity (MMbtus per year) (1)	Source of Biogas	Ownership	Expected Commercial Operation Date (5)
RNG Projects in Operation:
Greentree	1,061,712	LFG	100%	N/A
Imperial	1,061,712	LFG	100%	N/A
Emerald (2) (3)	1,327,140	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)	48,573	Dairy	10%	N/A
Sunoma (4)	192,350	Dairy	90%	N/A
Sub total	5,244,241
RNG Projects in Construction:
Prince William	1,725,282	LFG	100%	First quarter 2024
Hilltop (6)	255,500	Dairy	100%	Third quarter 2024
Vander Schaaf (6)	255,500	Dairy	100%	Fourth quarter 2024
Polk County	1,060,000	LFG	100%	Fourth quarter 2024
Sapphire (2)	796,284	LFG	50%	Third quarter 2024
Atlantic	331,785	LFG	50%	Mid 2025
Sub total	4,424,351
Total	9,668,592

(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) Emerald completed commissioning and commenced operations during the third quarter of 2023.

(4) 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.

(5) 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.

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(6) Achievement of these commissioning dates is subject to receipt of certain permits and successful resolution of a series of change order requests from the Engineering, Procurement and Construction contractor responsible for the design and construction of the projects’ facilities, which the Company has disputed. For additional information, please see Note 17 Commitments and contingencies to the financial statements.

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)
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	—
Prince William I (4)	1.9	Yes
Prince William II (5)	4.8	Yes
Old Dominion	8.0	Yes
Total	112.5

(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) It is currently contemplated that the Prince William I renewable power plant will continue operations through approximately December 2023.

(5) It is currently contemplated that the Prince William II renewable power plant will continue operations through approximately December 2023.

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Comparison of the Three and Nine Months Ended September 30, 2023 and 2022

The following table presents the period-over-period change for each line item in the Company's statement of operations for the three and nine months ended September 30, 2023 and 2022.

	Three Months Ended September 30,				$ Change		% Change		Nine Months Ended September 30,				$  Change		% Change
(in thousands)	2023		2022						2023		2022
Revenues:
RNG fuel	$	20,088	$	18,293	$	1,795	10	%	$	37,468	$	48,815	$	(11,347)	(23)	%
Fuel station services	37,305		35,771		1,534		4	%	88,089		87,376		713		1	%
Renewable Power	13,708		12,486		1,222		10	%	43,543		32,623		10,920		33	%
Total revenues	71,101		66,550		4,551		7	%	169,100		168,814		286		—	%
Operating expenses:
Cost of sales - RNG fuel	8,896		10,872		1,976		18	%	24,303		27,043		2,740		10	%
Cost of sales - Fuel station services	31,887		30,837		(1,050)		(3)	%	79,655		74,130		(5,525)		(7)	%
Cost of sales - Renewable power	11,112		7,645		(3,467)		(45)	%	28,251		23,593		(4,658)		(20)	%
Selling, general, and administrative	13,594		15,751		2,157		14	%	41,729		34,561		(7,168)		(21)	%
Depreciation, amortization, and accretion	3,739		3,380		(359)		(11)	%	10,934		10,101		(833)		8	%
Total expenses	69,228		68,485		(743)		1	%	184,872		169,428		(15,444)		9	%
Operating income (loss)	1,873		(1,935)		3,808		197	%	(15,772)		(614)		(15,158)		(2469)	%
Other income (expense)
Interest and financing expense, net	(2,885)		(790)		(2,095)		(265)	%	(4,482)		(7,212)		2,730		38	%
Loss on debt extinguishment	(953)		—		(953)		(100)	%	(2,848)		—		(2,848)		(100)	%
Change in fair value of derivative instruments, net	(138)		(1,908)		1,770		93	%	4,955		(1,580)		6,535		414	%
Other income	604		6,308		(5,704)		(90)	%	123,645		6,308		117,337		1860	%
Income (loss) income from equity method investments	1,726		3,694		(1,968)		(53)	%	1,433		3,658		(2,225)		(61)	%
Net income (loss) before provision for income taxes	227		5,369		(5,142)		(96)	%	106,931		560		106,371		18995	%
Provision for income taxes	—		—		—		—	%	—		—		—		—	%
Net income (loss)	227		5,369		(5,142)		(96)	%	106,931		560		106,371		18995	%
Net (loss) income attributable to redeemable non-controlling interests	(2,104)		4,161		(6,265)		(151)	%	83,123		(2,584)		85,707		3317	%
Net loss attributable to non-redeemable non-controlling interests	(51)		(325)		274		84	%	(531)		(824)		293		36	%
Paid-in-kind preferred dividends	2,782		2,658		124		5	%	8,394		5,093		3,301		65	%
Net income attributable to Class A Common stockholders	(400)		(1,125)		725		64	%	15,945		(1,125)		17,070		1,517	%

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Revenues

The following table shows revenues earned by product for the three and nine months ended September 30, 2023 and 2022:

(in thousands)		Three Months Ended September 30,			Nine Months Ended September 30,
	2023		2022	$ Change	2023	2022	$ Change
RNG Fuel
Brown gas sales		972	4,251	(3,279)	3,403	9,390	(5,987)
Environmental Attributes (1)		19,116	14,042	5,074	34,065	39,425	(5,360)
Total RNG Fuel		20,088	18,293	1,795	37,468	48,815	(11,347)
Fuel Station Services
OPAL owned stations		4,895	7,014	(2,119)	13,421	13,099	322
RNG marketing		11,956	5,710	6,246	21,728	19,005	2,723
Third party station service and maintenance		5,270	4,835	435	15,489	14,196	1,293
Construction		15,184	18,212	(3,028)	37,451	41,076	(3,625)
Total Fuel Station Services		37,305	35,771	1,534	88,089	87,376	713
Renewable Power
Electricity sales		9,170	10,943	(1,773)	27,760	30,095	(2,335)
Environmental Attributes (2)		4,538	1,543	2,995	15,783	2,528	13,255
Total Renewable Power		13,708	12,486	1,222	43,543	32,623	10,920
Total Revenues		71,101	66,550	4,551	169,100	168,814	286

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

(2) Revenues from Environmental Attributes in Renewable Power segment include revenues earned from sales of ISCC carbon sales and RECs.

RNG Fuel

Revenue from RNG Fuel increased by $1.8 million, or 10% for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This is primarily due to an increase of $5.1 million from the sale of Environmental Attributes consisting of a $0.3 million increase from the sale of 5,192 LCFS credits in the current quarter. There were no LCFS credit sales in 2022. There was a net increase of $4.8 million from the sale of an additional 2.0 million RINs offset by lower pricing in the current quarter compared to the third quarter of 2022. This was offset by a decrease in revenues of $3.3 million from the sale of brown gas due to lower commodity pricing.

Revenue from RNG Fuel decreased by $11.3 million, or 23%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. The decrease is primarily due to a decrease of $5.4 million from sale of environmental credits ($1.4 million volume variance from sale of 0.4 million less RINs sold in 2023 compared to 2022 and decrease of $4.0 million from price variance as a result of decrease of RIN pricing year over year). There was a decrease of $6.0 million from brown gas sales due to lower pricing year over year.

Fuel Station Services

Revenue from Fuel Station Services increased by $1.5 million, or 4%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This is primarily due to increase of $6.2 million in RNG marketing revenues out of which $3.5 million is from volume variance from delivering 1.2 million additional RINs, $2.5 million increase in RIN minting services offset by negative pricing variance of $0.4 million representing a decrease of $0.32 per RIN and $0.5 million increase in service revenues. There was a decrease of $2.1 million from brown gas sales at OPAL owned station due to lower pricing year over year and a decrease of $2.8 million in construction revenues due to timing of recognition of revenues in construction projects.

Revenue from Fuel Station Services increased by $0.7 million, or 1%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. This was primarily attributable to $1.3 million increase in service

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revenues due to nine new service and ownership sites, $2.7 million increase in RNG marketing revenues from RIN and LCFS generation revenues from new supply contracts and release of stored gas, $0.3 million increase in brown gas sales at OPAL owned stations due to higher volumes from six new ownership sites offset by decrease of $3.4 million construction revenues due to timing of construction projects.

Renewable Power

Revenue from Renewable Power increased by $1.2 million, or 10%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This is primarily due to increase of $3.0 million from the sale of ISCC Carbon Credits and REC sales offset by loss of revenues of $1.2 million from the planned shutdown of one Renewable Power facility in September 2022 and $0.6 million from another Renewable Power facility as it converted to an RNG facility.

Revenue from Renewable Power increased by $10.9 million, or 33%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. This change was attributable primarily to increase of $13.2 million from ISCC Carbon Credit sales and REC sales offset by decrease of $2.3 million from the planned shutdown of one of the Renewable Power facility.

Cost of sales

RNG Fuel

Cost of sales from RNG Fuel decreased by $2.0 million, or 18%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This is primarily due to the decrease of $0.6 million in start-up costs in New River as the facility came online in second quarter of 2022 and decrease in royalty expenses from lower RIN pricing.

Cost of sales from RNG Fuel decreased by $2.7 million, or 10%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. This is primarily due to a decrease in royalty expenses from lower RIN pricing, lower development costs from deconsolidation of Emerald and Sapphire and lower dispensing fees.

Fuel Station Services

Cost of sales from Fuel Station Services increased by $1.1 million, or 3%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This is primarily due to $2.5 million increase in cost of goods sold for third party inventory of environmental credits, $3.0 million increase in rebates and dispensing fees for environmental credits, offset by a $1.9 million decrease in brown gas pricing, $2.8 million decrease in construction costs in line with the decrease in construction revenues.

Cost of sales from Fuel Station Services increased by $5.5 million, or 7%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. This change was attributable primarily to a $6.7 million increase in dispensing and cost of goods sold on third party inventory of environmental credits, a $2.2 million increase in service costs for new sites offset by decrease of $2.7 million in construction costs and a $0.9 million decrease in brown gas costs from lower commodity pricing.

Renewable Power

Cost of sales from Renewable Power increased by $3.5 million, or 45%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This is primarily due to a $1.3 million termination payment made on a power purchase agreement at one our Renewable Power facilities and $1.2 million of expenses related to a facility which was converted to an RNG project.

Cost of sales from Renewable Power increased by $4.7 million, or 20%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. This is primarily due to a $1.3 million termination payment made on a power purchase agreement at one our Renewable Power facilities, $1.7 million increase in major maintenance expense, $1.4 million increase in royalty expense related to ISCC Carbon Credits and $1.2 million of expenses related to a facility which was converted to an RNG project offset by savings from planned shut down of one of our Renewable Power facilities.

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Selling, general, and administrative

Selling, general, and administrative expenses decreased by a total of $2.2 million, or 14%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This is primarily due to higher insurance cost of $5.0 million in the third quarter of 2022 on directors and officers tail policy offset by increase in stock-based compensation expense of $1.5 million, $0.6 million increase in legal and third party fees related to debt extinguishment and $0.7 million increase in compensation costs year over year.

Selling, general, and administrative expenses increased by a total of $7.2 million, or 21%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. This is primarily due to an increase in costs from compensation and benefits by $5.0 million, $0.6 million increase in legal and third party fees related to debt extinguishment, $1.1 million increase in legal fees and stock-based compensation expense of $4.1 million offset by savings in insurance expense on directors and officers tail policy of $3.1 million and $0.7 million savings in audit fees.

Depreciation, amortization, and accretion

Depreciation, amortization, and accretion marginally increased by a total of $0.4 million, or 11%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022.

Depreciation, amortization, and accretion increased by a total of $0.8 million, or 8%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. This is primarily due to increase in depreciation expense in OPAL Fuel Station Services segment due to increase in owned stations and $0.3 million increase as New River came online in second quarter of 2022.

Interest and financing expense, net

Interest and financing expenses, net increased by $2.1 million, or 265%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This is primarily due to $2.7 million of negative mark to market change recorded in the third quarter of 2022 on Convertible Note Payable when 50% of it was converted to equity upon closing of the Business Combination and the 10% premium on the remaining outstanding balance expired. This was offset by savings of $1.1 million on the Senior Secured Credit Facility as the debt was fully repaid in first quarter of 2023 and there was an increase in interest expense on the OPAL Term Loan of $0.5 million as interest rates as well as the outstanding debt increased year over year.

Interest and financing expenses, net decreased by $2.7 million, or 38%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. This is primarily due to savings of $2.3 million on the Senior Secured Credit Facility as the loan was fully repaid in the first quarter of 2023, $1.4 million savings on the OPAL Term Loan due to capitalized interest offset by increase in interest rates and debt outstanding year over year, an increase in interest income of $0.9 million offset by increase of $1.7 million in the interest expense of Convertible Note Payable as there was a negative mark to market change in the comparable quarter in the prior year.

Loss on debt extinguishment

On May 30, 2023, OPAL Intermediate Holdco 2 assigned to Paragon its rights and obligations under OPAL Term Loan II. The joint venture partner of Paragon reimbursed the Company $0.8 million as its portion of the transaction costs incurred.

The Company expensed the remaining deferred financing costs of $1.9 million as loss on debt extinguishment in its condensed consolidated statement of operations for the three and nine months ended September 30, 2023. Additionally, the Company completed a debt restructuring of the OPAL Term Loan in third quarter of 2023 which was accounted for as a debt modification and the Company recorded a loss on debt extinguishment of $0.9 million.

There was no loss on debt extinguishment for the three and nine months ended September 30, 2022.

Change in fair value of derivatives, net

Change in fair value of derivatives, net decreased by $1.8 million, or 93%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This is primarily because there were public and private warrants and put options outstanding as of September 30, 2022. However, the warrants were exchanged in the fourth quarter of 2022 and the put option expired in January 2023. The change in fair value for current quarter includes only earnout liabilities.

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Change in fair value of derivatives, net increased by $6.5 million, or 414%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. In 2023, the change in fair value of derivative instruments represents mark to market change on earnout liabilities which decreased in value. In 2022, the Company had additional derivative instruments including public and private warrants, put options and interest rate swaps on the Senior Secured Credit Facility.

Other income

Other income decreased by $5.7 million, or (90)%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This is primarily due to $4.3 million gain recorded on extinguishment of contingent liability and $1.9 million gain on repayment of a note receivable recorded in third quarter of 2022. The other income in the current quarter represents gain on transfer of RINs as consideration for services rendered in our OPAL Fuel Station Services segment.

Other income increased by $117.3 million or 1860%, for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. This is primarily attributable to $122.9 million gain recorded on deconsolidation of VIEs offset by $6.3 million gain on extinguishment of a contingent liability and repayment of note receivable recorded prior year.

Income (loss) from equity method investments

Net income attributable to equity method investments decreased by $2.0 million, or 53%, for the three months ended September 30, 2023 compared to the three months ended September 30, 2022. This change was attributable to a $3.2 million gain on settlement of commodity swap contracts as our portion from GREP in the prior year quarter.

Net loss attributable to equity method investments decreased by $2.2 million or 61% for the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022. This is primarily because we recorded $3.2 million gain on settlement of commodity swap contracts as our portion from GREP in the third quarter of 2022 and increase in net income from Pine Bend and Noble Road offset by the amortization of basis differences of $1.6 million in 2023.

Net income attributable to redeemable non-controlling interests

Net income attributable to redeemable non-controlling interests decreased by $6.3 million or 151%. The net income for the three months ended September 30, 2023 and 2022 reflects the portion of earnings belonging to OPAL Fuels equity holders.

Net income attributable to redeemable non-controlling interests increased by $85.7 million or 3317% and reflects the portion of earnings belonging to OPAL Fuels equity holders.

Net loss attributable to non-redeemable non-controlling interests

Net loss attributable to non-redeemable non-controlling interests for the three months ended September 30, 2023 decreased compared to three months ended September 30, 2022. This reflects the joint venture partners' loss in certain RNG facilities in which we sold a portion of our ownership interests but are consolidated in our financial statements. These entities for the three months ended September 30, 2023 were Sunoma and Central Valley and in 2022 we had Emerald, Sapphire, Sunoma and Central Valley.

Net loss attributable to non-redeemable non-controlling interests for the nine months ended September 30, 2023 decreased marginally compared to nine months ended September 30, 2022. This reflects the joint venture partners' loss in certain RNG facilities in which we sold a portion of our ownership interests but are consolidated in our financial statements. These entities for the nine months ended September 30, 2023 were Sunoma, Central Valley and five months of Emerald and Sapphire and in 2022, we had Emerald, Sapphire, Sunoma and Central Valley.

Paid-in-kind preferred dividends

On November 29, 2021, we entered into an Exchange Agreement with Hillman whereby Hillman exchanged its ownership interests in the four RNG projects of $30.0 million into 300,000 series A-1 preferred units at a par value of $100 per unit and 1.4% of the common units of OPAL Fuels. On the same day, we entered into a Subscription Agreement with NextEra for up to 1,000,000 Series A preferred units, which were issued to NextEra during first and second quarters of 2022 for total proceeds of $100.0 million. Upon completion of the Business Combination, these were converted to redeemable preferred non-controlling interests.

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Redeemable preferred non-controlling interests carry an interest of 8% dividend payable quarterly either in cash or paid-in-kind for the first eight quarters at the option of the Company. The Company recorded the dividends payable of $2.8 million and $8.4 million for the three and nine months ended September 30, 2023, respectively. The Company recorded the dividends payable of $2.7 million and $5.1 million for the three and nine months ended September 30, 2022, respectively as to be paid-in-kind.

During the third quarter of 2023, the Company repaid $16.5 million of paid-in-kind preferred dividends and as of September 30, 2023, the principal amount of $130.0 million of Redeemable preferred non-controlling interests is outstanding.

Liquidity and Capital Resources

Liquidity

As of September 30, 2023, our liquidity consisted of cash and cash equivalents including restricted cash of $21.6 million and $18.0 million of short term investments. Additionally, we have availability of $285.9 million under the delayed draw term loan and $41.0 million under the revolver facility under the OPAL Term Loan.

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 of September 30, 2023, we had total indebtedness excluding deferred financing costs of $187.1 million in principal amount which primarily consists of $164.1 million under the OPAL Term Loan and $23.0 million under Sunoma Loan.

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 7. Borrowings, to our condensed consolidated financial statements.

Cash Flows

The following table presents the Company's cash flows for the nine months ended September 30, 2023 and 2022:

	Nine Months Ended June 30,
(in thousands)	2023		2022
Net cash provided by (used in) from operating activities	$	4,827	$	(22,004)
Net cash used in investing activities	(44,918)		(219,215)
Net cash (used in) provided by from financing activities	(15,542)		270,525
Net (decrease) increase in cash, restricted cash, and cash equivalents	$	(55,633)	$	29,306

Net Cash Provided by Operating Activities

Net cash provided by operating activities for the nine months ended September 30, 2023 was $4.8 million, an increase of $26.8 million compared to net cash used in operations of $22.0 million for the nine months ended September 30, 2022.

65

The increase in cash provided by operating activities was attributable to an increase in net income and positive working capital changes primarily from decrease in accounts receivable, related party.

Net Cash Used in Investing Activities

Net cash used in investing activities for the nine months ended September 30, 2023 was $44.9 million, a decrease of $174.3 million compared to the $219.2 million used in investing activities for the nine months ended September 30, 2022. This was primarily due to a decrease in cash invested in short term investments of $193.8 million, deconsolidation of VIEs net cash of $11.9 million and an increase in distribution from equity method investment of $11.2 million offset by an increase in payments made for the construction of various RNG generation and dispensing facilities of $7.0 million and the repayment of Note receivable of $10.8 million in the third quarter of 2022.

Net Cash Provided by Financing Activities

Net cash used in financing activities for the nine months ended September 30, 2023 was $15.5 million, a decrease of $286.1 million compared to the $270.5 million provided from financing activities for the nine months ended September 30, 2022. This was primarily due to a decrease of $138.9 million from closing of Business Combination and $100.0 million decrease from proceeds from issuance of Redeemable Preferred Units to NextEra in the prior year, repayments of $19.1 million of Senior Secured Facility, the repurchase of $16.4 million of shares of our Class A common stock in connection with the exercise of the put option and decrease of $10.4 million proceeds from non-redeemable non-controlling interests.

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 September 30, 2023, we anticipate spending approximately $179.3 million in capital expenditures for the next 12 months for projects and fuel stations currently under construction and our share of contributions in our equity method investment projects. 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 7. Borrowings and Note 8. Leases to our condensed consolidated financial statements for additional information.

We believe that our cash and cash equivalents on hand, anticipated cash flows from operations and our access to expected sources of capital will be sufficient to meet our anticipated funding needs. We continue to pursue additional funding opportunities for growth and streamlining of our capital structure.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

The Company is not required to provide the information required by this Item as 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) and 15d-15(e) under the Exchange Act. The term “disclosure controls and procedures,” as defined in the

66

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 SEC'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 of September 30, 2023, our Co-Chief Executive Officers and Chief Financial Officer concluded that, as of such date, our disclosure controls and procedures were ineffective for the period covered by this report based on the material weakness in our internal control over financial reporting described below.

Previously Reported Material Weakness

In connection with the preparation and audit of our consolidated financial statements for each of the years ended December 31, 2022 and 2021, material weaknesses were identified in our internal control over financial reporting. A material weakness is a deficiency, or combination of deficiencies, in internal control over financial reporting such that there is a reasonable possibility that a material misstatement of its annual or interim consolidated financial statements will not be prevented, or detected and corrected, on a timely basis.

The material weaknesses identified were as follows:

●    There is a lack of an adequate control environment, including internal communications, to allow for timeliness of reviews for the accounting and disclosures of significant and unusual transactions and contracts;

●    We did not have timely and effective reviews over standard account reconciliations and related accounting analysis which resulted in various audit adjustments that we corrected; and

●    Review controls over application of ASC-606 were not designed and implemented appropriately during the current year.

We performed additional analysis and procedures with respect to accounts impacted by the material weakness in order to conclude that our consolidated financial statements in this report, and for the three and nine months ended September 30, 2023 and 2022, are fairly presented, in all material respects, in accordance with GAAP.

Under “Changes in Internal Controls over Financial Reporting” and “Remediation Plans” below, we describe our remediation plan to address the identified material weakness.

Management's Quarterly Report on Internal Control over Financial Reporting

This Quarterly Report on Form 10-Q does not include a report of management's assessment regarding internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) or an attestation report of our independent registered public accounting firm due to a transition period established by rules of the SEC for newly public companies.

Changes in Internal Controls over Financial Reporting

The design and implementation of internal controls over financial reporting for the Company subsequent to the Business Combination has required and will continue to require significant time and resources from management and other personnel. The changes to our internal control over financial reporting commenced during the period covered by this report and after will materially affect, or are reasonably likely to materially affect, our internal control over financial reporting by establishing new controls and procedures appropriate to the operating business we have become as a result of the Business Combination.

Remediation Plans

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We continue to take steps to remediate the identified material weaknesses and will take such necessary steps until such remediation is complete. These steps included the following:

a) Hiring additional accounting and financial reporting personnel with appropriate technical accounting knowledge to identify and review accounting conclusions on all complex technical accounting matters that impact our financial statements. We obtain assistance from third party resources on as needed basis.

b) Designing and implementing new controls for capturing and identifying significant and unusual transactions in a timely manner.

c) Designing and implementing new controls to strengthen the internal review processes for accounting of significant and unusual transactions.

d) Designing and implementing new controls by creating new or enhancing existing reconciliation templates for balance sheet accounts including accrued construction in progress, accrued dispensing payables and inter company eliminations.

e) Creating a robust account reconciliation review process by enhancing the review procedures performed to validate the accuracy of the account balances.

f) Implementing general information technology controls over our financial reporting system by disabling the functionality for the same employee to prepare and post journal entries.

g) Designing and implementing new controls over revenue accounting and application of ASC 606. An inventory of all revenue contracts and corresponding accounting treatment as per ASC 606 has been prepared and periodic training to all accounting personnel is being performed. Implemented detailed account reconciliation template to validate accurate reporting of revenue accounts for environmental credit monetization services and gain on transfer of RINs and LCFSs between Fuel Station Services and equity method investments.

h) Performing a quarterly review of all contracts entered into by the Company and assessing ASC 606 impact and confirming that the revenue has been recorded correctly in the reporting periods.

i) Reporting regularly to the Company's Audit Committee on the progress and results of the remediation plan, including the identification, status and resolution of internal control deficiencies.

The above stated controls have been implemented during the first three quarters of 2023. As we work to improve our internal control environment over financial reporting, we may modify our remediation plan and implement additional controls as we continue to enhance our financial reporting controls. The material weaknesses will not be considered remediated until the remediated controls have been operating effectively for sufficient time and evaluated through testing of operating effectiveness.

    The effectiveness of our internal control over financial reporting is subject to various inherent limitations, including cost limitations, judgments used in decision making, assumptions about the likelihood of future events, the possibility of human error and the risk of fraud. If we are unable to remediate the material weaknesses identified, our ability to record, process and report financial information accurately, and to prepare financial statements within the time periods specified by the forms of the SEC, could be adversely affected which, in turn, may adversely affect our reputation and business and the market price of our securities, including the Class A common stock. In addition, any such failures could result in litigation or regulatory actions by the SEC or other regulatory authorities, loss of investor confidence, delisting of our securities and harm to our reputation and financial condition, or diversion of financial and management resources from the operation of our business.

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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.

Item 1A. Risk Factors 

There have been no material changes from the “Risk Factors” previously disclosed in our Annual Report on Form 10-K for the year ended December 31, 2022, filed with the SEC on March 29, 2023. The risks described in the Annual Report on Form 10-K for the year ended December 31, 2022 are not the only risks facing us. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

Item 2. Unregistered Sales of Equity Securities, Use of Proceeds and Issuer Purchases of Equity Securities

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

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Item 5. Other Information

Rule 10b5-1 Trading Plans

During the fiscal quarter ended September 30, 2023, none of the Company’s directors or executive officers adopted or terminated any contract, instruction or written plan for the purchase or sale of Company securities that was intended to satisfy the affirmative defense conditions of Rule 10b5-1(c) or any “non-Rule 10b5-1 trading arrangement.”

Item 6. Exhibits

Exhibit Index

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†#*	Third Amended and Restated Gas Sale and Purchase Agreement, dated August 11, 2023 (incorporated by reference to Exhibit 10.5 to the registrant’s Quarterly Report on Form 10-Q filed with the SEC on August 14, 2023)
10.2†#*	Landfill Gas Purchase and Sale Agreement, dated August 28, 2023 with Waste Management of California, Inc. (incorporated by reference to Exhibit 10.1 to the registrant’s Current Report on Form 8-K filed with the SEC on August 31, 2023)
10.3†#*	Lease Agreement, dated August 28, 2023 with Waste Management of California, Inc. (incorporated by reference to Exhibit 10.2 to the registrant’s Current Report on Form 8-K filed with the SEC on August 31, 2023)
10.4†#*	Landfill Gas Purchase and Sale Agreement, dated August 28, 2023 with Guadalupe Rubbish Disposal Co., Inc. (incorporated by reference to Exhibit 10.3 to the registrant’s Current Report on Form 8-K filed with the SEC on August 31, 2023)
10.5†#	Lease Agreement, dated August 28, 2023 with Guadalupe Rubbish Disposal Co., Inc. (incorporated by reference to Exhibit 10.4 to the registrant’s Current Report on Form 8-K filed with the SEC on August 31, 2023)
10.6*	Credit Agreement, dated September 1, 2023, by and among Intermediate HoldCo as Borrower, the guarantors, the lenders party thereto, Bank of America, N.A. as the administration agent, and Apterra Infrastructure Capital LLC, Barclays Bank PLC, BofA Securities, Inc., Celtic Bank Corporation, JP Morgan Chase Bank, N.A. and Investec Inc., as joint lead arrangers (incorporated by reference to Exhibit 10.1 to the registrant’s Current Report on Form 8-K filed with the SEC on September 5, 2023)
10.7*	Pledge Agreement, dated September 1, 2023, by OPAL Fuels Parent Holdco 3 LLC in favor of Bank of America, N.A. (incorporated by reference to Exhibit 10.2 to the registrant’s Current Report on Form 8-K filed with the SEC on September 5, 2023)
10.8*	Security Agreement, dated September 1, 2023, by OPAL Fuels Intermediate HoldCo LLC and the other grantors listed on the signature pages thereto in favor of Bank of America, N.A. (incorporated by reference to Exhibit 10.3 to the registrant’s Current Report on Form 8-K filed with the SEC on September 5, 2023)
10.9*	Note (Term), dated September 1, 2023, between OPAL Fuels Intermediate HoldCo LLC and BankUnited, N.A. (incorporated by reference to Exhibit 10.4 to the registrant’s Current Report on Form 8-K filed with the SEC on September 5, 2023)
10.10*	Note (Revolving), dated September 1, 2023, between OPAL Fuels Intermediate HoldCo LLC and BankUnited, N.A. (incorporated by reference to Exhibit 10.5 to the registrant’s Current Report on Form 8-K filed with the SEC on September 5, 2023)
10.11*	Agreement, dated September 14, 2023, by and among OPAL L2G and SJI (incorporated by reference to Exhibit 10.1 to the registrant’s Current Report on Form 8-K filed with the SEC on September 20, 2023)
10.12#	Base Contract for Sale and Purchase of Natural Gas (San Diego), dated September 15, 2023
10.13#	Base Contract for Sale and Purchase of Natural Gas (Richmond), dated September 15, 2023
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.

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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).

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

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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: November 14, 2023

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/ Ann Anthony
Name:	Ann Anthony
Title:	Chief Financial Officer

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EX-10.12

Exhibit 10.12

PORTIONS OF INFORMATION CONTAINED IN THIS AGREEMENT HAVE BEEN

EXCLUDED FROM THIS AGREEMENT BECAUSE THEY ARE BOTH NOT MATERIAL AND

THE TYPE THAT THE REGISTRANT TREATS AS PRIVATE OR CONFIDENTIAL.
EXCLUDED INFORMATION IS MARKED AS [***] BELOW

Base Contract for Sale and Purchase of Natural Gas

This Base Contract is entered into as of the following date: September 15, 2023.

The parties to this Base Contract are the following:

PARTY A MM San Diego LLC	PARTY NAME	PARTY B [***]
c/o OPAL Fuels Inc. One North Lexington Avenue White Plains, NY 10601	ADDRESS	[***]
www.opalfuels.com	BUSINESS WEBSITE	[***]
	CONTRACT NUMBER
	D-U-N-S® NUMBER
■US FEDERAL OTHER:	TAX ID NUMBERS	US FEDERAL: ■OTHER: [***]
Delaware	JURISDICTION OF ORGANIZATION	Amsterdam, The Netherlands
Corporation    ■ LLC Limited Partnership    Partnership LLP Other:	COMPANY TYPE	Corporation    LLC Limited Partnership    Partnership LLP    ■ Other: private limited company
	GUARANTOR (IF APPLICABLE)
CONTACT INFORMATION
ATTN: [***] TEL#: [***] EMAIL: [***]	COMMERCIAL	ATTN: [***] TEL#:    FAX#: N/A EMAIL: [***]
ATTN: [***] TEL#: [***] EMAIL: [***]	SCHEDULING	ATTN: TEL#: FAX#: EMAIL:
ATTN: General Counsel TEL#: N/A FAX#: N/A EMAIL: noticeofficer@opalfuels.com	CONTRACT AND LEGAL NOTICES	ATTN:    Legal Department TEL#: N/A    FAX#: N/A EMAIL: [***]
ATTN: TEL#: FAX#: EMAIL:	CREDIT	ATTN: TEL#: FAX#: EMAIL:
ATTN: [***] TEL#: [***] EMAIL: [***]	TRANSACTION CONFIRMATION	ATTN: [***] TEL#:    FAX#: N/A EMAIL: [***]
ACCOUNTING INFORMATION

ATTN: [***] TEL#: [***] EMAIL: [***]	INVOICES PAYMENTS SETTLEMENTS	ATTN: [***] TEL#:    FAX#: N/A EMAIL: [***]
BANK: [***] ABA: [***] ACCT: [***] OTHER DETAILS: [***]	WIRE TRANSFER NUMBERS (IF APPLICABLE)	BANK: ABA: ACCT: OTHER DETAILS:
BANK: ABA: ACCT: OTHER DETAILS:	ACH NUMBERS (IF APPLICABLE)	BANK: [***] ABA:     ACCT: [***] OTHER DETAILS: [***]
ATTN: ADDRESS:	CHECKS (IF APPLICABLE)	ATTN: ADDRESS:

Copyright © 2006 North American Energy Standards Board, Inc. All Rights Reserved

NAESB Standard 6.3.1

September 5, 2006 (Revised by R15003/R15007, April 4, 2016)

DocuSign Envelope ID: 3B7EF782-2D4B-4907-8852-773EE4FC4166

Base Contract for Sale and Purchase of Natural Gas

(Continued)

This Base Contract incorporates by reference for all purposes the General Terms and Conditions for Sale and Purchase of Natural Gas published by the North American Energy Standards Board. The parties hereby agree to the following provisions offered in said General Terms and Conditions. In the event the parties fail to check a box, the specified default provision shall apply. Select the appropriate box(es) from eachsection:

Copyright © 2006 North American Energy Standards Board, Inc.

NAESB Standard 6.3.1

September 5, 2006 (Revised by R15003/R15007, April 4, 2016)

All Rights Reserved

Page 2 of 13

DocuSign Envelope ID: 3B7EF782-2D4B-4907-8852-773EE4FC4166

Section 1.2 Transaction Procedure	Oral (default) OR ■Written	Section 10.2 Additional Events of Default	■No Additional Events of Default (default) Indebtedness Cross Default Party A: Party B: Transactional Cross Default
Section 2.7 Confirm Deadline	■2 Business Days after receipt (default) OR Business Days after receipt
Section 2.8 Confirming Party	Seller (default) OR Buyer ■Buyer and Seller
Section 3.2 Performance Obligation	■Cover Standard (default) OR Spot Price Standard	Section 10.3.1 Early Termination Damages	■Early Termination Damages Apply (default) OR Early Termination Damages Do Not Apply
Note: The following Spot Price Publication applies to both of the immediately preceding.		Section 10.3.2 Other Agreement Setoffs	■Other Agreement Setoffs Apply (default) ■Bilateral (default) Triangular OR Other Agreement Setoffs Do Not Apply
Section 2.31 Spot Price Publication	Gas Daily Midpoint (default) OR
Section 6 Taxes	Buyer Pays At and After Delivery Point (default) OR Seller Pays Before and At Delivery Point
Section 7.2 Payment Date	■25th Day of Month following Month of delivery (default) OR Day of Month following Month of delivery	Section 15.5 Choice Of Law	New York
Section 7.2 Method of Payment	■Wire transfer (default) Automated Clearinghouse Credit (ACH) Check	Section 15.10 Confidentiality	■Confidentiality applies (default) OR Confidentiality does not apply
Section 7.7 Netting	■Netting applies (default) OR Netting does not apply
Special Provisions Number of sheets attached: None Addendum(s):

IN WITNESS WHEREOF, the parties hereto have executed this Base Contract in duplicate.

Copyright © 2006 North American Energy Standards Board, Inc.

NAESB Standard 6.3.1

September 5, 2006 (Revised by R15003/R15007, April 4, 2016)

All Rights Reserved

Page 2 of 13

DocuSign Envelope ID: 3B7EF782-2D4B-4907-8852-773EE4FC4166

MM San Diego LLC	PARTY NAME	[***]
By: /s/ Jonathan Maurer	SIGNATURE	By:     By:
Jonathan Maurer	PRINTED NAME	[***]
CO-CEO	TITLE	[***]

Copyright © 2006 North American Energy Standards Board, Inc.

NAESB Standard 6.3.1

September 5, 2006 (Revised by R15003/R15007, April 4, 2016)

All Rights Reserved

Page 2 of 13

DocuSign Envelope ID: 3B7EF782-2D4B-4907-8852-773EE4FC4166

General Terms and Conditions

Base Contract for Sale and Purchase of Natural Gas

SECTION 1.    PURPOSE AND PROCEDURES

1.1. These General Terms and Conditions are intended to facilitate purchase and sale transactions of Gas on a Firm or Interruptible basis. "Buyer" refers to the party receiving Gas and "Seller" refers to the party delivering Gas. The entire agreement between the parties shall be the Contract as defined in Section 2.9.

The parties have selected either the “Oral Transaction Procedure” or the “Written Transaction Procedure” as indicated on the Base Contract.

Oral Transaction Procedure:

1.2. The parties will use the following Transaction Confirmation procedure. Any Gas purchase and sale transaction may be effectuated in an EDI transmission or telephone conversation with the offer and acceptance constituting the agreement of the parties. The parties shall be legally bound from the time they so agree to transaction terms and may each rely thereon. Any such transaction shall be considered a “writing” and to have been “signed”. Notwithstanding the foregoing sentence, the parties agree that Confirming Party shall, and the other party may, confirm a telephonic transaction by sending the other party a Transaction Confirmation by facsimile, EDI or mutually agreeable electronic means within three Business Days of a transaction covered by this Section 1.2 (Oral Transaction Procedure) provided that the failure to send a Transaction Confirmation shall not invalidate the oral agreement of the parties. Confirming Party adopts its confirming letterhead, or the like, as its signature on any Transaction Confirmation as the identification and authentication of Confirming Party. If the Transaction Confirmation contains any provisions other than those relating to the commercial terms of the transaction (i.e., price, quantity, performance obligation, delivery point, period of delivery and/or transportation conditions), which modify or supplement the Base Contract or General Terms and Conditions of this Contract (e.g., arbitration or additional representations and warranties), such provisions shall not be deemed to be accepted pursuant to Section 1.3 but must be expressly agreed to by both parties; provided that the foregoing shall not

invalidate any transaction agreed to by the parties.

Written Transaction Procedure:

1.2. The parties will use the following Transaction Confirmation procedure. Should the parties come to an agreement regarding a Gas purchase and sale transaction for a particular Delivery Period, the Confirming Party shall, and the other party may, record that agreement on a Transaction Confirmation and communicate such Transaction Confirmation by facsimile, EDI or mutually agreeable electronic means, to the other party by the close of the Business Day following the date of agreement. The parties acknowledge that their agreement will not be binding until the exchange of nonconflicting Transaction Confirmations or the

passage of the Confirm Deadline without objection from the receiving party, as provided in Section 1.3.

1.3.If a sending party's Transaction Confirmation is materially different from the receiving party's understanding of the agreement referred to in Section 1.2, such receiving party shall notify the sending party via facsimile, EDI or mutually agreeable electronic means by the Confirm Deadline, unless such receiving party has previously sent a Transaction Confirmation to the sending party. The failure of the receiving party to so notify the sending party in writing by the Confirm Deadline constitutes the receiving party's agreement to the terms of the transaction described in the sending party's Transaction Confirmation. If there are any material differences between timely sent Transaction Confirmations governing the same transaction, then neither Transaction Confirmation shall be binding until or unless such differences are resolved including the use of any evidence that clearly resolves the differences in the Transaction Confirmations. In the event of a conflict among the terms of (i) a binding Transaction Confirmation pursuant to Section 1.2, (ii) the oral agreement of the parties which may be evidenced by a recorded conversation, where the parties have selected the Oral Transaction Procedure of the Base Contract,

(iii) the Base Contract, and (iv) these General Terms and Conditions, the terms of the documents shall govern in the priority listed in this sentence.

1.4.The parties agree that each party may electronically record all telephone conversations with respect to this Contract between their respective employees, without any special or further notice to the other party. Each party shall obtain any necessary consent of its agents and employees to such recording. Where the parties have selected the Oral Transaction Procedure in Section 1.2 of the Base Contract, the parties agree not to contest the validity or enforceability of telephonic recordings entered into in accordance with the requirements of this Base Contract.

SECTION 2.    DEFINITIONS

The terms set forth below shall have the meaning ascribed to them below. Other terms are also defined elsewhere in the Contract and shall have the meanings ascribed to them herein.

2.1.“Additional Event of Default” shall mean Transactional Cross Default or Indebtedness Cross Default, each as and if selected by the parties pursuant to the Base Contract.

Copyright © 2006 North American Energy Standards Board, Inc.

NAESB Standard 6.3.1

September 5, 2006 (Revised by R15003/R15007, April 4, 2016)

All Rights Reserved

Page 3 of #NUM_PAGES#

DocuSign Envelope ID: 3B7EF782-2D4B-4907-8852-773EE4FC4166

2.2.“Affiliate” shall mean, in relation to any person, any entity controlled, directly or indirectly, by the person, any entity that controls, directly or indirectly, the person or any entity directly or indirectly under common control with the person. For this purpose, “control” of any entity or person means ownership of at least 50 percent of the voting power of the entity or person.

Copyright © 2006 North American Energy Standards Board, Inc.

NAESB Standard 6.3.1

September 5, 2006 (Revised by R15003/R15007, April 4, 2016)

All Rights Reserved

Page 4 of #NUM_PAGES#

DocuSign Envelope ID: 3B7EF782-2D4B-4907-8852-773EE4FC4166

2.3.“Alternative Damages” shall mean such damages, expressed in dollars or dollars per MMBtu, as the parties shall agree upon in the Transaction Confirmation, in the event either Seller or Buyer fails to perform a Firm obligation to deliver Gas in the case of Seller or to receive Gas in the case of Buyer.

2.4."Base Contract" shall mean a contract executed by the parties that incorporates these General Terms and Conditions by reference; that specifies the agreed selections of provisions contained herein; and that sets forth other information required herein and any Special Provisions and addendum(s) as identified on page one.

2.5."British thermal unit" or "Btu" shall mean the International BTU, which is also called the Btu (IT).

2.6."Business Day(s)" shall mean Monday through Friday, excluding Federal Banking Holidays for transactions in the U.S.

2.7."Confirm Deadline" shall mean 5:00 p.m. in the receiving party's time zone on the second Business Day following the Day a Transaction Confirmation is received or, if applicable, on the Business Day agreed to by the parties in the Base Contract; provided, if the Transaction Confirmation is time stamped after 5:00 p.m. in the receiving party's time zone, it shall be deemed received at the opening of the next Business Day.

2.8."Confirming Party" shall mean the party designated in the Base Contract to prepare and forward Transaction Confirmations to the other party.

2.9."Contract" shall mean the legally-binding relationship established by (i) the Base Contract, (ii) any and all binding Transaction Confirmations and (iii) where the parties have selected the Oral Transaction Procedure in Section 1.2 of the Base Contract, any and all transactions that the parties have entered into through an EDI transmission or by telephone, but that have not been confirmed in a binding Transaction Confirmation, all of which shall form a single integrated agreement between the parties.

2.10."Contract Price" shall mean the amount expressed in U.S. Dollars per MMBtu to be paid by Buyer to Seller for the purchase of Gas as agreed to by the parties in a transaction.

2.11."Contract Quantity" shall mean the quantity of Gas to be delivered and taken as agreed to by the parties in a transaction.

2.12."Cover Standard", as referred to in Section 3.2, shall mean that if there is an unexcused failure to take or deliver any quantity of Gas pursuant to this Contract, then the performing party shall use commercially reasonable efforts to (i) if Buyer is the performing party, obtain Gas, (or an alternate fuel if elected by Buyer and replacement Gas is not available), or (ii) if Seller is the performing party, sell Gas, in either case, at a price reasonable for the delivery or production area, as applicable, consistent with: the amount of notice provided by the nonperforming party; the immediacy of the Buyer's Gas consumption needs or Seller's Gas sales requirements, as applicable; the quantities involved; and the anticipated length of failure by the nonperforming party.

2.13."Credit Support Obligation(s)” shall mean any obligation(s) to provide or establish credit support for, or on behalf of, a party to this Contract such as cash, an irrevocable standby letter of credit, a margin agreement, a prepayment, a security interest in an asset, guaranty, or other good and sufficient security of a continuing nature.

2.14."Day" shall mean a period of 24 consecutive hours, coextensive with a "day" as defined by the Receiving Transporter in a particular transaction.

2.15."Delivery Period" shall be the period during which deliveries are to be made as agreed to by the parties in a transaction.

2.16."Delivery Point(s)" shall mean such point(s) as are agreed to by the parties in a transaction.

2.17."EDI" shall mean an electronic data interchange pursuant to an agreement entered into by the parties, specifically relating to the communication of Transaction Confirmations under this Contract.

2.18."EFP" shall mean the purchase, sale or exchange of natural Gas as the "physical" side of an exchange for physical transaction involving gas futures contracts. EFP shall incorporate the meaning and remedies of "Firm", provided that a party’s excuse for nonperformance of its obligations to deliver or receive Gas will be governed by the rules of the relevant futures exchange re gulated under the Commodity Exchange Act.

2.19."Firm" shall mean that either party may interrupt its performance without liability only to the extent that such performance is prevented for reasons of Force Majeure; provided, however, that during Force Majeure interruptions, the party invoking Force Majeure may be responsible for any Imbalance Charges as set forth in Section 4.3 related to its interruption after the nomination is made to the Transporter and until the change in deliveries and/or receipts is confirmed by the Transporter.

2.20."Gas" shall mean any mixture of hydrocarbons and noncombustible gases in a gaseous state consisting primarily of methane.

2.21.“Guarantor” shall mean any entity that has provided a guaranty of the obligations of a party hereunder.

2.22."Imbalance Charges" shall mean any fees, penalties, costs or charges (in cash or in kind) assessed by a Transporter for failure to satisfy the Transporter's balance and/or nomination requirements.

2.23.“Indebtedness Cross Default” shall mean if selected on the Base Contract by the parties with respect to a party, that it or its Guarantor, if any, experiences a default, or similar condition or event however therein defined, under one or more agreements or instruments, individually or collectively, relating to indebtedness (such indebtedness to include any obligation whether present or future, contingent or otherwise, as principal or surety or otherwise) for the payment or repayment of borrowed money in an aggregate amount greater than the threshold specified in the Base Contract with respect to such party or its Guarantor, if any, which results in such indebtedness becoming immediately due and payable.

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2.24."Interruptible" shall mean that either party may interrupt its performance at any time for any reason, whether or not caused by an event of Force Majeure, with no liability, except such interrupting party may be responsible for any Imbalance Charges as set

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forth in Section 4.3 related to its interruption after the nomination is made to the Transporter and until the change in deliveries and/or receipts is confirmed by Transporter.

2.25."MMBtu" shall mean one million British thermal units, which is equivalent to one dekatherm.

2.26."Month" shall mean the period beginning on the first Day of the calendar month and ending immediately prior to the commencement of the first Day of the next calendar month.

2.27."Payment Date" shall mean a date, as indicated on the Base Contract, on or before which payment is due Seller for Gas received by Buyer in the previous Month.

2.28."Receiving Transporter" shall mean the Transporter receiving Gas at a Delivery Point, or absent such receiving Transporter, the Transporter delivering Gas at a Delivery Point.

2.29."Scheduled Gas" shall mean the quantity of Gas confirmed by Transporter(s) for movement, transportation or management.

2.30.“Specified Transaction(s)” shall mean any other transaction or agreement between the parties for the purchase, sale or exchange of physical Gas, and any other transaction or agreement identified as a Specified Transaction under the Base Contract.

2.31."Spot Price " as referred to in Section 3.2 shall mean the price listed in the publication indicated on the Base Contract, under the listing applicable to the geographic location closest in proximity to the Delivery Point(s) for the relevant Day; provided, if there is no single price published for such location for such Day, but there is published a range of prices, then the Spot Price shall be the average of such high and low prices. If no price or range of prices is published for such Day, then the Spot Price shall be the average of the following: (i) the price (determined as stated above) for the first Day for which a price or range of prices is published that next precedes the relevant Day; and (ii) the price (determined as stated above) for the first Day for which a price or range of prices is published that next follows the relevant Day.

2.32."Transaction Confirmation" shall mean a document, similar to the form of Exhibit A, setting forth the terms of a transaction formed pursuant to Section 1 for a particular Delivery Period.

2.33.“Transactional Cross Default” shall mean if selected on the Base Contract by the parties with respect to a party, that it shall be in default, however therein defined, under any Specified Transaction.

2.34.“Termination Option” shall mean the option of either party to terminate a transaction in the event that the other party fails to perform a Firm obligation to deliver Gas in the case of Seller or to receive Gas in the case of Buyer for a designated number of days during a period as specified on the applicable Transaction Confirmation.

2.35."Transporter(s)" shall mean all Gas gathering or pipeline companies, or local distribution companies, acting in the capacity of a transporter, transporting Gas for Seller or Buyer upstream or downstream, respectively, of the Delivery Point pursuant to a particular transaction.

SECTION 3.    PERFORMANCE OBLIGATION

3.1.Seller agrees to sell and deliver, and Buyer agrees to receive and purchase, the Contract Quantity for a particular transaction in accordance with the terms of the Contract. Sales and purchases will be on a Firm or Interruptible basis, as agreed to by the parties in a transaction.

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The parties have selected either the “Cover Standard” or the “Spot Price Standard” as indicated on the Base Contract.

Cover Standard:

3.2. The sole and exclusive remedy of the parties in the event of a breach of a Firm obligation to deliver or receive Gas shall be recovery of the following: (i) in the event of a breach by Seller on any Day(s), payment by Seller to Buyer in an amount equal to the positive difference, if any, between the purchase price paid by Buyer utilizing the Cover Standard and the Contract Price, adjusted for commercially reasonable differences in transportation costs to or from the Delivery Point(s), multiplied by the difference between the Contract Quantity and the quantity actually delivered by Seller for such Day(s) excluding any quantity for which no replacement is available; or (ii) in the event of a breach by Buyer on any Day(s), payment by Buyer to Seller in the amount equal to the positive difference, if any, between the Contract Price and the price received by Seller utilizing the Cover Standard for the resale of such Gas, adjusted for commercially reasonable differences in transportation costs to or from the Delivery Point(s), multiplied by the difference between the Contract Quantity and the quantity actually taken by Buyer for such Day(s) excluding any quantity for which no sale is available; and (iii) in the event that Buyer has used commercially reasonable efforts to replace the Gas or Seller has used commercially reasonable efforts to sell the Gas to a third party, and no such replacement or sale is available for all or any portion of the Contract Quantity of Gas, then in addition to (i) or (ii) above, as applicable, the sole and exclusive remedy of the performing party with respect to the Gas not replaced or sold shall be an amount equal to any unfavorable difference between the Contract Price and the Spot Price, adjusted for such transportation to the applicable Delivery Point, multiplied by the quantity of such Gas not replaced or sold. Imbalance Charges shall not be recovered under this Section 3.2, but Seller and/or Buyer shall be responsible for Imbalance Charges, if any, as provided in Section 4.3. The amount of such unfavorable difference shall be payable five Business Days after presentation of the performing party’s invoice,

which shall set forth the basis upon which such amount was calculated.

Spot Price Standard:

3.2. The sole and exclusive remedy of the parties in the event of a breach of a Firm obligation to deliver or receive Gas shall be recovery of the following: (i) in the event of a breach by Seller on any Day(s), payment by Seller to Buyer in an amount equal to the difference between the Contract Quantity and the actual quantity delivered by Seller and received by Buyer for such Day(s),

multiplied by the positive difference, if any, obtained by subtracting the Contract Price from the Spot Price; or (ii) in the event of a

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breach by Buyer on any Day(s), payment by Buyer to Seller in an amount equal to the difference between the Contract Quantity and the actual quantity delivered by Seller and received by Buyer for such Day(s), multiplied by the positive difference, if any, obtained by subtracting the applicable Spot Price from the Contract Price. Imbalance Charges shall not be recovered under this Section 3.2, but Seller and/or Buyer shall be responsible for Imbalance Charges, if any, as provided in Section 4.3. The amount of such unfavorable difference shall be payable five Business Days after presentation of the performing party’s invoice, which

shall set forth the basis upon which such amount was calculated.

3.3.Notwithstanding Section 3.2, the parties may agree to Alternative Damages in a Transaction Confirmation executed in writing by both parties.

3.4.In addition to Sections 3.2 and 3.3, the parties may provide for a Termination Option in a Transaction Confirmation executed in writing by both parties. The Transaction Confirmation containing the Termination Option will designate the length of nonperformance triggering the Termination Option and the procedures for exercise thereof, how damages for nonperformance will be compensated, and how liquidation costs will be calculated.

SECTION 4.    TRANSPORTATION, NOMINATIONS, AND IMBALANCES

4.1.Seller shall have the sole responsibility for transporting the Gas to the Delivery Point(s). Buyer shall have the sole responsibility for transporting the Gas from the Delivery Point(s).

4.2.The parties shall coordinate their nomination activities, giving sufficient time to meet the deadlines of the affected Transporter(s). Each party shall give the other party timely prior Notice, sufficient to meet the requirements of all Transporter(s) involved in the transaction, of the quantities of Gas to be delivered and purchased each Day. Should either party become aware that actual deliveries at the Delivery Point(s) are greater or lesser than the Scheduled Gas, such party shall promptly notify the other party.

4.3.The parties shall use commercially reasonable efforts to avoid imposition of any Imbalance Charges. If Buyer or Seller receives an invoice from a Transporter that includes Imbalance Charges, the parties shall determine the validity as well as the cause of such Imbalance Charges. If the Imbalance Charges were incurred as a result of Buyer’s receipt of quantities of Gas greater than or less than the Scheduled Gas, then Buyer shall pay for such Imbalance Charges or reimburse Seller for such Imbalance Charges paid by Seller. If the Imbalance Charges were incurred as a result of Seller’s delivery of quantities of Gas greater than or less than the Scheduled Gas, then Seller shall pay for such Imbalance Charges or reimburse Buyer for such Imbalance Charges paid by Buyer.

SECTION 5.    QUALITY AND MEASUREMENT

All Gas delivered by Seller shall meet the pressure, quality and heat content requirements of the Receiving Transporter. The unit of quantity measurement for purposes of this Contract shall be one MMBtu dry. Measurement of Gas quantities hereunder shall be in accordance with the established procedures of the Receiving Transporter.

SECTION 6. TAXES

The parties have selected either “Buyer Pays At and After Delivery Point” or “Seller Pays Before and At Delivery Point” as indicated on the Base Contract.

Buyer Pays At and After Delivery Point:

Seller shall pay or cause to be paid all taxes, fees, levies, penalties, licenses or charges imposed by any government authority (“Taxes”) on or with respect to the Gas prior to the Delivery Point(s). Buyer shall pay or cause to be paid all Taxes on or with respect to the Gas at the Delivery Point(s) and all Taxes after the Delivery Point(s). If a party is required to remit or pay Taxes that are the other party’s responsibility hereunder, the party responsible for such Taxes shall promptly reimburse the other party for such Taxes. Any party entitled to an exemption from any such Taxes or charges shall furnish the other party any necessary documentation thereof.

Seller Pays Before and At Delivery Point:

Seller shall pay or cause to be paid all taxes, fees, levies, penalties, licenses or charges imposed by any government authority (“Taxes”) on or with respect to the Gas prior to the Delivery Point(s) and all Taxes at the Delivery Point(s). Buyer shall pay or cause to be paid all Taxes on or with respect to the Gas after the Delivery Point(s). If a party is required to remit or pay Taxes that are the other party’s responsibility hereunder, the party responsible for such Taxes shall promptly reimburse the other party for such Taxes. Any party entitled to an exemption from any such Taxes or charges shall furnish the other party any necessary documentation thereof.

SECTION 7.    BILLING, PAYMENT, AND AUDIT

7.1.Seller shall invoice Buyer for Gas delivered and received in the preceding Month and for any other applicable charges, providing supporting documentation acceptable in industry practice to support the amount charged. If the actual quantity delivered is not known by the billing date, billing will be prepared based on the quantity of Scheduled Gas. The invoiced quantity will then be adjusted to the actual quantity on the following Month's billing or as soon thereafter as actual delivery information is available.

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7.2.Buyer shall remit the amount due under Section 7.1 in the manner specified in the Base Contract, in immediately available funds, on or before the later of the Payment Date or 10 Days after receipt of the invoice by Buyer; provided that if the Payment Date is not a Business Day, payment is due on the next Business Day following that date. In the event any payments are due Buyer hereunder, payment to Buyer shall be made in accordance with this Section 7.2.

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7.3.In the event payments become due pursuant to Sections 3.2 or 3.3, the performing party may submit an invoice to the nonperforming party for an accelerated payment setting forth the basis upon which the invoiced amount was calculated. Payment from the nonperforming party will be due five Business Days after receipt of invoice.

7.4.If the invoiced party, in good faith, disputes the amount of any such invoice or any part thereof, such invoiced party will pay such amount as it concedes to be correct; provided, however, if the invoiced party disputes the amount due, it must provide supporting documentation acceptable in industry practice to support the amount paid or disputed without undue delay. In the event the parties are unable to resolve such dispute, either party may pursue any remedy available at law or in equity to enforce its rights pursuant to this Section.

7.5.If the invoiced party fails to remit the full amount payable when due, interest on the unpaid portion shall accrue from the date due until the date of payment at a rate equal to the lower of (i) the then-effective prime rate of interest published under "Money Rates" by The Wall Street Journal, plus two percent per annum; or (ii) the maximum applicable lawful interest rate.

7.6.A party shall have the right, at its own expense, upon reasonable Notice and at reasonable times, to examine and audit and to obtain copies of the relevant portion of the books, records, and telephone recordings of the other party only to the extent reasonably necessary to verify the accuracy of any statement, charge, payment, or computation made under the Contract. This right to examine, audit, and to obtain copies shall not be available with respect to proprietary information not directly relevant to transactions under this Contract. All invoices and billings shall be conclusively presumed final and accurate and all associated claims for under- or overpayments shall be deemed waived unless such invoices or billings are objected to in writing, with adequate explanation and/or documentation, within two years after the Month of Gas delivery. All retroactive adjustments under Section 7 shall be paid in full by the party owing payment within 30 Days of Notice and substantiation of such inaccuracy.

7.7.Unless the parties have elected on the Base Contract not to make this Section 7.7 applicable to this Contract, the parties shall net all undisputed amounts due and owing, and/or past due, arising under the Contract such that the party owing the greater amount shall make a single payment of the net amount to the other party in accordance with Section 7; provided that no payment required to be made pursuant to the terms of any Credit Support Obligation or pursuant to Section 7.3 shall be subject to netting under this Section. If the parties have executed a separate netting agreement, the terms and conditions therein shall prevail to the extent inconsistent herewith.

SECTION 8.    TITLE, WARRANTY, AND INDEMNITY

8.1.Unless otherwise specifically agreed, title to the Gas shall pass from Seller to Buyer at the Delivery Point(s). Seller shall have responsibility for and assume any liability with respect to the Gas prior to its delivery to Buyer at the specified Delivery Point(s). Buyer shall have responsibility for and assume any liability with respect to said Gas after its delivery to Buyer at the Delivery Point(s).

8.2.Seller warrants that it will have the right to convey and will transfer good and merchantable title to all Gas sold hereunder and delivered by it to Buyer, free and clear of all liens, encumbrances, and claims. EXCEPT AS PROVIDED IN THIS SECTION 8.2 AND IN SECTION 15.8, ALL OTHER WARRANTIES, EXPRESS OR IMPLIED, INCLUDING ANY WARRANTY OF MERCHANTABILITY OR OF FITNESS FOR ANY PARTICULAR PURPOSE, ARE DISCLAIMED.

8.3.Seller agrees to indemnify Buyer and save it harmless from all losses, liabilities or claims including reasonable attorneys' fees and costs of court ("Claims"), from any and all persons, arising from or out of claims of title, personal injury (including death) or property damage from said Gas or other charges thereon which attach before title passes to Buyer. Buyer agrees to indemnify Seller and save it harmless from all Claims, from any and all persons, arising from or out of claims regarding payment, personal injury (including death) or property damage from said Gas or other charges thereon which attach after title passes to Buyer.

8.4.The parties agree that the delivery of and the transfer of title to all Gas under this Contract shall take place within the Customs Territory of the United States (as defined in general note 2 of the Harmonized Tariff Schedule of the United States 19 U.S.C. §1202, General Notes, page 3); provided, however, that in the event Seller took title to the Gas outside the Customs Territory of the United States, Seller represents and warrants that it is the importer of record for all Gas entered and delivered into the United States, and shall be responsible for entry and entry summary filings as well as the payment of duties, taxes and fees, if any, and all applicable record keeping requirements.

8.5.Notwithstanding the other provisions of this Section 8, as between Seller and Buyer, Seller will be liable for all Claims to the extent that such arise from the failure of Gas delivered by Seller to meet the quality requirements of Section 5.

SECTION 9.    NOTICES

9.1.All Transaction Confirmations, invoices, payment instructions, and other communications made pursuant to the Base Contract ("Notices") shall be made to the addresses specified in writing by the respective parties from time to time.

9.2.All Notices required hereunder shall be in writing and may be sent by facsimile or mutually acceptable electronic means, a nationally recognized overnight courier service, first class mail or hand delivered.

9.3.Notice shall be given when received on a Business Day by the addressee. In the absence of proof of the actual receipt date, the following presumptions will apply. Notices sent by facsimile shall be deemed to have been received upon the sending party's receipt of its facsimile machine's confirmation of successful transmission. If the day on which such facsimile is received is not a Business Day or is after five p.m. on a Business Day, then such facsimile shall be deemed to have been received on the next

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following Business Day. Notice by overnight mail or courier shall be deemed to have been received on the next Business Day after it was sent or such earlier time as is confirmed by the receiving party. Notice via first class mail shall be considered delivered five Business Days after mailing.

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9.4.The party receiving a commercially acceptable Notice of change in payment instructions or other payment information shall not be obligated to implement such change until ten Business Days after receipt of such Notice.

SECTION 10.    FINANCIAL RESPONSIBILITY

10.1.If either party (“X”) has reasonable grounds for insecurity regarding the performance of any obligation under this Contract (whether or not then due) by the other party (“Y”) (including, without limitation, the occurrence of a material change in the creditworthiness of Y or its Guarantor, if applicable), X may demand Adequate Assurance of Performance. “Adequate Assurance of Performance” shall mean sufficient security in the form, amount, for a term, and from an issuer, all as reasonably acceptable to X, including, but not limited to cash, a standby irrevocable letter of credit, a prepayment, a security interest in an asset or guaranty. Y hereby grants to X a continuing first priority security interest in, lien on, and right of setoff against all Adequate Assurance of Performance in the form of cash transferred by Y to X pursuant to this Section 10.1. Upon the return by X to Y of such Adequate Assurance of Performance, the security interest and lien granted hereunder on that Adequate Assurance of Performance shall be released automatically and, to the extent possible, without any further action by either party.

10.2.In the event (each an "Event of Default") either party (the "Defaulting Party") or its Guarantor shall: (i) make an assignment or any general arrangement for the benefit of creditors; (ii) file a petition or otherwise commence, authorize, or acquiesce in the commencement of a proceeding or case under any bankruptcy or similar law for the protection of creditors or have such petition filed or proceeding commenced against it; (iii) otherwise become bankrupt or insolvent (however evidenced); (iv) be unable to pay its debts as they fall due; (v) have a receiver, provisional liquidator, conservator, custodian, trustee or other similar official appointed with respect to it or substantially all of its assets; (vi) fail to perform any obligation to the other party with respect to any Credit Support Obligations relating to the Contract; (vii) fail to give Adequate Assurance of Performance under Section 10.1 within 48 hours but at least one Business Day of a written request by the other party; (viii) not have paid any amount due the other party hereunder on or before the second Business Day following written Notice that such payment is due; or ix) be the affected party with respect to any Additional Event of Default; then the other party (the "Non-Defaulting Party") shall have the right, at its sole election, to immediately withhold and/or suspend deliveries or payments upon Notice and/or to terminate and liquidate the transactions under the Contract, in the manner provided in Section 10.3, in addition to any and all other remedies available hereunder.

10.3.If an Event of Default has occurred and is continuing, the Non-Defaulting Party shall have the right, by Notice to the Defaulting Party, to designate a Day, no earlier than the Day such Notice is given and no later than 20 Days after such Notice is given, as an early termination date (the “Early Termination Date”) for the liquidation and termination pursuant to Section 10.3.1 of all transactions under the Contract, each a “Terminated Transaction”. On the Early Termination Date, all transactions will terminate, other than those transactions, if any, that may not be liquidated and terminated under applicable law (“Excluded Transactions”), which Excluded Transactions must be liquidated and terminated as soon thereafter as is legally permissible, and upon termination shall be a Terminated Transaction and be valued consistent with Section 10.3.1 below. With respect to each Excluded Transaction, its actual termination date shall be the Early Termination Date for purposes of Section 10.3.1.

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The parties have selected either “Early Termination Damages Apply” or “Early Termination Damages Do Not Apply” as indicated on the Base Contract.

Early Termination Damages Apply:

10.3.1. As of the Early Termination Date, the Non-Defaulting Party shall determine, in good faith and in a commercially reasonable manner, (i) the amount owed (whether or not then due) by each party with respect to all Gas delivered and received between the parties under Terminated Transactions and Excluded Transactions on and before the Early Termination Date and all other applicable charges relating to such deliveries and receipts (including without limitation any amounts owed under Section 3.2), for which payment has not yet been made by the party that owes such payment under this Contract and (ii) the Market Value, as defined below, of each Terminated Transaction. The Non-Defaulting Party shall (x) liquidate and accelerate each Terminated Transaction at its Market Value, so that each amount equal to the difference between such Market Value and the Contract Value, as defined below, of such Terminated Transaction(s) shall be due to the Buyer under the Terminated Transaction(s) if such Market Value exceeds the Contract Value and to the Seller if the opposite is the case; and (y) where appropriate, discount each amount then due under clause (x) above to present value in a commercially reasonable manner as of the Early Termination Date (to take account of the period between the date of liquidation and the date on which such amount would have otherwise been due pursuant to the relevant Terminated Transactions).

For purposes of this Section 10.3.1, “Contract Value” means the amount of Gas remaining to be delivered or purchased under a transaction multiplied by the Contract Price, and “Market Value” means the amount of Gas remaining to be delivered or purchased under a transaction multiplied by the market price for a similar transaction at the Delivery Point determined by the Non-Defaulting Party in a commercially reasonable manner. To ascertain the Market Value, the Non-Defaulting Party may consider, among other valuations, any or all of the settlement prices of NYMEX Gas futures contracts, quotations from leading dealers in energy swap contracts or physical gas trading markets, similar sales or purchases and any other bona fide third-party offers, all adjusted for the length of the term and differences in transportation costs. A party shall not be required to enter into a replacement transaction(s) in order to determine the Market Value. Any extension(s) of the term of a transaction to which parties are not bound as of the Early Termination Date (including but not limited to “evergreen provisions”) shall not be considered in determining Contract Values and Market Values. For the avoidance of doubt, any option pursuant to which one party has the right to extend

the term of a transaction shall be considered in determining Contract Values and Market Values. The rate of interest used in calculating net present value shall be determined by the Non-Defaulting Party in a commercially reasonable manner.

Early Termination Damages Do Not Apply:

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10.3.1. As of the Early Termination Date, the Non-Defaulting Party shall determine, in good faith and in a commercially reasonable manner, the amount owed (whether or not then due) by each party with respect to all Gas delivered and received between the parties under Terminated Transactions and Excluded Transactions on and before the Early Termination Date and all other applicable charges relating to such deliveries and receipts (including without limitation any amounts owed under Section

3.2), for which payment has not yet been made by the party that owes such payment under this Contract.

The parties have selected either “Other Agreement Setoffs Apply” or “Other Agreement Setoffs Do Not Apply” as indicated on the Base Contract.

Other Agreement Setoffs Apply:

Bilateral Setoff Option:

10.3.2. The Non-Defaulting Party shall net or aggregate, as appropriate, any and all amounts owing between the parties under Section 10.3.1, so that all such amounts are netted or aggregated to a single liquidated amount payable by one party to the other (the “Net Settlement Amount”). At its sole option and without prior Notice to the Defaulting Party, the Non-Defaulting Party is hereby authorized to setoff any Net Settlement Amount against (i) any margin or other collateral held by a party in connection with any Credit Support Obligation relating to the Contract; and (ii) any amount(s) (including any excess cash margin or excess cash collateral) owed or held by the party that is entitled to the Net Settlement Amount under any other agreement or arrangement between the parties.

Triangular Setoff Option:

10.3.2. The Non-Defaulting Party shall net or aggregate, as appropriate, any and all amounts owing between the parties under Section 10.3.1, so that all such amounts are netted or aggregated to a single liquidated amount payable by one party to the other (the “Net Settlement Amount”). At its sole option, and without prior Notice to the Defaulting Party, the Non-Defaulting Party is hereby authorized to setoff (i) any Net Settlement Amount against any margin or other collateral held by a party in connection with any Credit Support Obligation relating to the Contract; (ii) any Net Settlement Amount against any amount(s) (including any excess cash margin or excess cash collateral) owed by or to a party under any other agreement or arrangement between the parties; (iii) any Net Settlement Amount owed to the Non-Defaulting Party against any amount(s) (including any excess cash margin or excess cash collateral) owed by the Non-Defaulting Party or its Affiliates to the Defaulting Party under any other agreement or arrangement; (iv) any Net Settlement Amount owed to the Defaulting Party against any amount(s) (including any excess cash margin or excess cash collateral) owed by the Defaulting Party to the Non-Defaulting Party or its Affiliates under any other agreement or arrangement; and/or (v) any Net Settlement Amount owed to the Defaulting Party against any amount(s) (including any excess cash margin or excess cash collateral) owed by the Defaulting Party or its Affiliates to the Non-Defaulting

Party under any other agreement or arrangement.

Other Agreement Setoffs Do Not Apply:

10.3.2. The Non-Defaulting Party shall net or aggregate, as appropriate, any and all amounts owing between the parties under Section 10.3.1, so that all such amounts are netted or aggregated to a single liquidated amount payable by one party to the other (the “Net Settlement Amount”). At its sole option and without prior Notice to the Defaulting Party, the Non-Defaulting Party

may setoff any Net Settlement Amount against any margin or other collateral held by a party in connection with any Credit Support Obligation relating to the Contract.

10.3.3. If any obligation that is to be included in any netting, aggregation or setoff pursuant to Section 10.3.2 is unascertained, the Non-Defaulting Party may in good faith estimate that obligation and net, aggregate or setoff, as applicable, in respect of the estimate, subject to the Non-Defaulting Party accounting to the Defaulting Party when the obligation is ascertained. Any amount not then due which is included in any netting, aggregation or setoff pursuant to Section 10.3.2 shall be discounted to net present value in a commercially reasonable manner determined by the Non-Defaulting Party.

10.4.As soon as practicable after a liquidation, Notice shall be given by the Non-Defaulting Party to the Defaulting Party of the Net Settlement Amount, and whether the Net Settlement Amount is due to or due from the Non-Defaulting Party. The Notice shall include a written statement explaining in reasonable detail the calculation of the Net Settlement Amount, provided that failure to give such Notice shall not affect the validity or enforceability of the liquidation or give rise to any claim by the Defaulting Party against the Non- Defaulting Party. The Net Settlement Amount as well as any setoffs applied against such amount pursuant to Section 10.3. 2, shall be paid by the close of business on the second Business Day following such Notice, which date shall not be earlier than the Early Termination Date. Interest on any unpaid portion of the Net Settlement Amount as adjusted by setoffs, shall accrue from the date due until the date of payment at a rate equal to the lower of (i) the then-effective prime rate of interest published under "Money Rates" by The Wall Street Journal, plus two percent per annum; or (ii) the maximum applicable lawful interest rate.

10.5.The parties agree that the transactions hereunder constitute a "forward contract" within the meaning of the United States Bankruptcy Code and that Buyer and Seller are each "forward contract merchants" within the meaning of the United States Bankruptcy Code.

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10.6.The Non-Defaulting Party's remedies under this Section 10 are the sole and exclusive remedies of the Non-Defaulting Party with respect to the occurrence of any Early Termination Date. Each party reserves to itself all other rights, setoffs, counterclaims and other defenses that it is or may be entitled to arising from the Contract.

10.7.With respect to this Section 10, if the parties have executed a separate netting agreement with close-out netting provisions, the terms and conditions therein shall prevail to the extent inconsistent herewith.

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SECTION 11.    FORCE MAJEURE

11.1.Except with regard to a party's obligation to make payment(s) due under Section 7, Section 10.4, and Imbalance Charges under Section 4, neither party shall be liable to the other for failure to perform a Firm obligation, to the extent such failure was caused by Force Majeure. The term "Force Majeure" as employed herein means any cause not reasonably within the control of the party claiming suspension, as further defined in Section 11.2.

11.2.Force Majeure shall include, but not be limited to, the following: (i) physical events such as acts of God, landslides, lightning, earthquakes, fires, storms or storm warnings, such as hurricanes, which result in evacuation of the affected area, floods, washouts, explosions, breakage or accident or necessity of repairs to machinery or equipment or lines of pipe; (ii) weather related events affecting an entire geographic region, such as low temperatures which cause freezing or failure of wells or lines of pipe;

(iii) interruption and/or curtailment of Firm transportation and/or storage by Transporters; (iv) acts of others such as strikes, lockouts or other industrial disturbances, riots, sabotage, insurrections or wars, or acts of terror; and (v) governmental actions such as necessity for compliance with any court order, law, statute, ordinance, regulation, or policy having the effect of law promulgated by a governmental authority having jurisdiction. Seller and Buyer shall make reasonable efforts to avoid the adverse impacts of a Force Majeure and to resolve the event or occurrence once it has occurred in order to resume performance.

11.3.Neither party shall be entitled to the benefit of the provisions of Force Majeure to the extent performance is affected by any or all of the following circumstances: (i) the curtailment of interruptible or secondary Firm transportation unless primary, in-path, Firm transportation is also curtailed; (ii) the party claiming excuse failed to remedy the condition and to resume the performance of such covenants or obligations with reasonable dispatch; or (iii) economic hardship, to include, without limitation, Seller’s ability to sell Gas at a higher or more advantageous price than the Contract Price, Buyer’s ability to purchase Gas at a lower or more advantageous price than the Contract Price, or a regulatory agency disallowing, in whole or in part, the pass through of costs resulting from this Contract; (iv) the loss of Buyer’s market(s) or Buyer’s inability to use or resell Gas purchased hereunder, except, in either case, as provided in Section 11.2; or (v) the loss or failure of Seller’s gas supply or depletion of reserves, except, in either case, as provided in Section 11.2. The party claiming Force Majeure shall not be excused from its responsibility for Imbalance Charges.

11.4.Notwithstanding anything to the contrary herein, the parties agree that the settlement of strikes, lockouts or other industrial disturbances shall be within the sole discretion of the party experiencing such disturbance.

11.5.The party whose performance is prevented by Force Majeure must provide Notice to the other party. Initial Notice may be given orally; however, written Notice with reasonably full particulars of the event or occurrence is required as soon as reasonably possible. Upon providing written Notice of Force Majeure to the other party, the affected party will be relieved of its obligation, from the onset of the Force Majeure event, to make or accept delivery of Gas, as applicable, to the extent and for the duration of Force Majeure, and neither party shall be deemed to have failed in such obligations to the other during such occurrence or event.

11.6.Notwithstanding Sections 11.2 and 11.3, the parties may agree to alternative Force Majeure provisions in a Transaction Confirmation executed in writing by both parties.

SECTION 12.    TERM

This Contract may be terminated on 30 Day’s written Notice, but shall remain in effect until the expiration of the latest Delivery Period of any transaction(s). The rights of either party pursuant to Section 7.6, Section 10, Section 13, the obligations to make payment hereunder, and the obligation of either party to indemnify the other, pursuant hereto shall survive the termination of the Base Contract or any transaction.

SECTION 13. LIMITATIONS

FOR BREACH OF ANY PROVISION FOR WHICH AN EXPRESS REMEDY OR MEASURE OF DAMAGES IS PROVIDED, SUCH EXPRESS REMEDY OR MEASURE OF DAMAGES SHALL BE THE SOLE AND EXCLUSIVE REMEDY. A PARTY’S LIABILITY HEREUNDER SHALL BE LIMITED AS SET FORTH IN SUCH PROVISION, AND ALL OTHER REMEDIES OR DAMAGES AT LAW OR IN EQUITY ARE WAIVED. IF NO REMEDY OR MEASURE OF DAMAGES IS EXPRESSLY PROVIDED HEREIN OR IN A TRANSACTION, A PARTY’S LIABILITY SHALL BE LIMITED TO DIRECT ACTUAL DAMAGES ONLY. SUCH DIRECT ACTUAL DAMAGES SHALL BE THE SOLE AND EXCLUSIVE REMEDY, AND ALL OTHER REMEDIES OR DAMAGES AT LAW OR IN EQUITY ARE WAIVED. UNLESS EXPRESSLY HEREIN PROVIDED, NEITHER PARTY SHALL BE LIABLE FOR CONSEQUENTIAL, INCIDENTAL, PUNITIVE, EXEMPLARY OR INDIRECT DAMAGES, LOST PROFITS OR OTHER BUSINESS INTERRUPTION DAMAGES, BY STATUTE, IN TORT OR CONTRACT, UNDER ANY INDEMNITY PROVISION OR OTHERWISE. IT IS THE INTENT OF THE PARTIES THAT THE LIMITATIONS HEREIN IMPOSED ON REMEDIES AND THE MEASURE OF DAMAGES BE WITHOUT REGARD TO THE CAUSE OR CAUSES RELATED THERETO, INCLUDING THE NEGLIGENCE OF ANY PARTY, WHETHER SUCH NEGLIGENCE BE SOLE, JOINT OR CONCURRENT, OR ACTIVE OR PASSIVE. TO THE EXTENT ANY DAMAGES REQUIRED TO BE PAID HEREUNDER ARE LIQUIDATED, THE PARTIES ACKNOWLEDGE THAT THE DAMAGES ARE DIFFICULT OR IMPOSSIBLE TO DETERMINE, OR OTHERWISE OBTAINING AN ADEQUATE REMEDY IS INCONVENIENT AND THE DAMAGES CALCULATED HEREUNDER CONSTITUTE A REASONABLE APPROXIMATION OF THE HARM OR LOSS.

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SECTION 14. MARKET DISRUPTION

If a Market Disruption Event has occurred then the parties shall negotiate in good faith to agree on a replacement price for the Floating Price (or on a method for determining a replacement price for the Floating Price) for the affected Day, and if the parties have not so agreed on or before the second Business Day following the affected Day then the replacement price for the Floating Price shall be determined within the next two following Business Days with each party obtaining, in good faith and from non-affiliated market participants in the relevant market, two quotes for prices of Gas for the affected Day of a similar quality and quantity in the geographical location closest in proximity to the Delivery Point and averaging the four quotes. If either party fails to provide two quotes then the average of the other party’s two quotes shall determine the replacement price for the Floating Price. "Floating Price" means the price or a factor of the price agreed to in the transaction as being based upon a specified index. "Market Disruption Event" means, with respect to an index specified for a transaction, any of the following events: (a) the failure of the index to announce or publish information necessary for determining the Floating Price; (b) the failure of trading to commence or the permanent discontinuation or material suspension of trading on the exchange or market acting as the index; (c) the temporary or permanent discontinuance or unavailability of the index; (d) the temporary or permanent closing of any exchange acting as the index; or (e) both parties agree that a material change in the formula for or the method of determining the Floating Price has occurred. For the purposes of the calculation of a replacement price for the Floating Price, all numbers shall be rounded to three decimal places. If the fourth decimal number is five or greater, then the third decimal number shall be increased by one and if the fourth decimal number is less than five, then the third decimal number shall remain unchanged.

SECTION 15. MISCELLANEOUS

15.1.This Contract shall be binding upon and inure to the benefit of the successors, assigns, personal representatives, and heirs of the respective parties hereto, and the covenants, conditions, rights and obligations of this Contract shall run for the full term of this Contract. No assignment of this Contract, in whole or in part, will be made without the prior written consent of the non-assigning party (and shall not relieve the assigning party from liability hereunder), which consent will not be unreasonably withheld or delayed; provided, either party may

(i) transfer, sell, pledge, encumber, or assign this Contract or the accounts, revenues, or proceeds hereof in connection with any financing or other financial arrangements, or (ii) transfer its interest to any parent or Affiliate by assignment, merger or otherwise without the prior approval of the other party. Upon any such assignment, transfer and assumption, the transferor shall remain principally liable for and shall not be relieved of or discharged from any obligations hereunder.

15.2.If any provision in this Contract is determined to be invalid, void or unenforceable by any court having jurisdiction, such determination shall not invalidate, void, or make unenforceable any other provision, agreement or covenant of this Contract.

15.3.No waiver of any breach of this Contract shall be held to be a waiver of any other or subsequent breach.

15.4.This Contract sets forth all understandings between the parties respecting each transaction subject hereto, and any prior contracts, understandings and representations, whether oral or written, relating to such transactions are merged into and superseded by this Contract and any effective transaction(s). This Contract may be amended only by a writing executed by both parties.

15.5.The interpretation and performance of this Contract shall be governed by the laws of the jurisdiction as indicated on the Base Contract, excluding, however, any conflict of laws rule which would apply the law of another jurisdiction.

15.6.This Contract and all provisions herein will be subject to all applicable and valid statutes, rules, orders and regulations of any governmental authority having jurisdiction over the parties, their facilities, or Gas supply, this Contract or transaction or any provisions thereof.

15.7.There is no third party beneficiary to this Contract.

15.8.Each party to this Contract represents and warrants that it has full and complete authority to enter into and perform this Contract. Each person who executes this Contract on behalf of either party represents and warrants that it has full and complete authority to do so and that such party will be bound thereby.

15.9.The headings and subheadings contained in this Contract are used solely for convenience and do not constitute a part of this Contract between the parties and shall not be used to construe or interpret the provisions of this Contract.

15.10.Unless the parties have elected on the Base Contract not to make this Section 15.10 applicable to this Contract, neither party shall disclose directly or indirectly without the prior written consent of the other party the terms of any transaction to a third party (other than the employees, lenders, royalty owners, counsel, accountants and other agents of the party, or prospective purchasers of all or substantially all of a party’s assets or of any rights under this Contract, provided such persons shall have agreed to keep such terms confidential) except (i) in order to comply with any applicable law, order, regulation, or exchange rule, (ii) to the extent necessary for the enforcement of this Contract

, (iii) to the extent necessary to implement any transaction, (iv) to the extent necessary to comply with a regulatory agency’s reporting requirements including but not limited to gas cost recovery proceedings; or (v) to the extent such information is delivered to such third party for the sole purpose of calculating a published index. Each party shall notify the other party of any proceeding of which it is aware which may result in disclosure of the terms of any transaction (other than as permitted hereunder) and use reasonable efforts to prevent or limit the disclosure. The existence of this Contract is not subject to this confidentiality obligation. Subject to Section 13, the parties shall be entitled to all remedies available at law or in equity to enforce, or seek relief in connection with this confidentiality obligation. The terms of any transaction hereunder shall be kept confidential by the parties hereto for one year from the expiration of the transaction.

In the event that disclosure is required by a governmental body or applicable law, the party subject to such requirement may disclose the material terms of this Contract to the extent so required, but shall promptly notify the other party, prior to disclosure ,

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and shall cooperate (consistent with the disclosing party’s legal obligations) with the other party’s efforts to obtain protective orders or similar restraints with respect to such disclosure at the expense of the other party.

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15.11.The parties may agree to dispute resolution procedures in Special Provisions attached to the Base Contract or in a Transaction Confirmation executed in writing by both parties

15.12.Any original executed Base Contract, Transaction Confirmation or other related document may be digitally copied, photocopied, or stored on computer tapes and disks (the “Imaged Agreement”). The Imaged Agreement, if introduced as evidence on paper, the Transaction Confirmation, if introduced as evidence in automated facsimile form, the recording, if introduced as evidence in its original form, and all computer records of the foregoing, if introduced as evidence in printed format, in any judicial, arbitration, mediation or administrative proceedings will be admissible as between the parties to the same extent and under the same conditions as other business records originated and maintained in documentary form. Neither Party shall object to the admissibility of the recording, the Transaction Confirmation, or the Imaged Agreement on the basis that such were not originated or maintained in documentary form. However, nothing herein shall be construed as a waiver of any other objection to the admissibility of such evidence.

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TRANSACTION CONFIRMATION    EXHIBIT A FOR IMMEDIATE DELIVERY

Letterhead/Logo		Date: , Transaction Confirmation #:
This Transaction Confirmation is subject to the Base Contract between Seller and Buyer dated . The terms of this Transaction Confirmation are binding unless disputed in writing within 2 Business Days of receipt unless otherwise specified in the Base Contract.
SELLER: Attn: Phone: Fax: Base Contract No. Transporter: Transporter Contract Number:	BUYER: Attn: Phone: Fax: Base Contract No. Transporter: Transporter Contract Number:
Contract Price: $/MMBtu or
Delivery Period: Begin: ,     End: ,
Performance Obligation and Contract Quantity: (Select One) Firm (Fixed Quantity):    Firm (Variable Quantity):    Interruptible: MMBtus/day    MMBtus/day Minimum    Up to MMBtus/day EFP    MMBtus/day Maximum subject to Section 4.2. at election of Buyer or    Seller
Delivery Point(s): (If a pooling point is used, list a specific geographic and pipeline location):
Special Conditions:
Seller: By: Title: Date:	Buyer: By: Title: Date:

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EX-10.13

Exhibit 10.13

PORTIONS OF INFORMATION CONTAINED IN THIS AGREEMENT HAVE BEEN

EXCLUDED FROM THIS AGREEMENT BECAUSE THEY ARE BOTH NOT MATERIAL AND

THE TYPE THAT THE REGISTRANT TREATS AS PRIVATE OR CONFIDENTIAL.
EXCLUDED INFORMATION IS MARKED AS [***] BELOW

Base Contract for Sale and Purchase of Natural Gas

This Base Contract is entered into as of the following date: September 15, 2023.

The parties to this Base Contract are the following:

PARTY A Richmond Energy LLC	PARTY NAME	PARTY B [***]
c/o OPAL Fuels Inc. One North Lexington Avenue White Plains, NY 10601	ADDRESS	[***]
www.opalfuels.com	BUSINESS WEBSITE	[***]
	CONTRACT NUMBER
	D-U-N-S® NUMBER
■US FEDERAL OTHER:	TAX ID NUMBERS	US FEDERAL: ■OTHER: [***]
Delaware	JURISDICTION OF ORGANIZATION	Amsterdam, The Netherlands
Corporation    ■ LLC Limited Partnership    Partnership LLP Other:	COMPANY TYPE	Corporation    LLC Limited Partnership    Partnership LLP    ■ Other: private limited company
	GUARANTOR (IF APPLICABLE)
CONTACT INFORMATION
ATTN: [***] TEL#: [***] EMAIL: [***]	COMMERCIAL	ATTN: [***] TEL#:    FAX#: N/A EMAIL: [***]
ATTN: [***] TEL#: [***] EMAIL: [***]	SCHEDULING	ATTN: TEL#: FAX#: EMAIL:
ATTN: General Counsel TEL#: N/A FAX#: N/A EMAIL: noticeofficer@opalfuels.com	CONTRACT AND LEGAL NOTICES	ATTN:    Legal Department TEL#: N/A    FAX#: N/A EMAIL: [***]
ATTN: TEL#: FAX#: EMAIL:	CREDIT	ATTN: TEL#: FAX#: EMAIL:
ATTN: [***] TEL#: [***] EMAIL: [***]	TRANSACTION CONFIRMATION	ATTN: [***] TEL#:    FAX#: N/A EMAIL: [***]
ACCOUNTING INFORMATION

DocuSign Envelope ID: 30E2A0D7-50C2-4407-B2AC-EAB1CA882E30

ATTN: [***] TEL#: [***] EMAIL: [***]	INVOICES PAYMENTS SETTLEMENTS	ATTN: [***] TEL#:    FAX#: N/A EMAIL: [***]
BANK: [***] ABA: [***]ACCT: [***] OTHER DETAILS: [***]	WIRE TRANSFER NUMBERS (IF APPLICABLE)	BANK: ABA: ACCT: OTHER DETAILS:
BANK: ABA: ACCT: OTHER DETAILS:	ACH NUMBERS (IF APPLICABLE)	BANK: [***] ABA:     ACCT: [***] OTHER DETAILS: [***]
ATTN: ADDRESS:	CHECKS (IF APPLICABLE)	ATTN: ADDRESS:

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NAESB Standard 6.3.1

September 5, 2006 (Revised by R15003/R15007, April 4, 2016)

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Base Contract for Sale and Purchase of Natural Gas

(Continued)

This Base Contract incorporates by reference for all purposes the General Terms and Conditions for Sale and Purchase of Natural Gas published by the North American Energy Standards Board. The parties hereby agree to the following provisions offered in said General Terms and Conditions. In the event the parties fail to check a box, the specified default provision shall apply. Select the appropriate box(es) from eachsection:

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Section 1.2 Transaction Procedure	Oral (default) OR ■Written	Section 10.2 Additional Events of Default	■No Additional Events of Default (default) Indebtedness Cross Default Party A: Party B: Transactional Cross Default
Section 2.7 Confirm Deadline	■2 Business Days after receipt (default) OR Business Days after receipt
Section 2.8 Confirming Party	Seller (default) OR Buyer ■Buyer and Seller
Section 3.2 Performance Obligation	■Cover Standard (default) OR Spot Price Standard	Section 10.3.1 Early Termination Damages	■Early Termination Damages Apply (default) OR Early Termination Damages Do Not Apply
Note: The following Spot Price Publication applies to both of the immediately preceding.		Section 10.3.2 Other Agreement Setoffs	■Other Agreement Setoffs Apply (default) ■Bilateral (default) Triangular OR Other Agreement Setoffs Do Not Apply
Section 2.31 Spot Price Publication	Gas Daily Midpoint (default) OR
Section 6 Taxes	Buyer Pays At and After Delivery Point (default) OR Seller Pays Before and At Delivery Point
Section 7.2 Payment Date	■25th Day of Month following Month of delivery (default) OR Day of Month following Month of delivery	Section 15.5 Choice Of Law	New York
Section 7.2 Method of Payment	■Wire transfer (default) Automated Clearinghouse Credit (ACH) Check	Section 15.10 Confidentiality	■Confidentiality applies (default) OR Confidentiality does not apply
Section 7.7 Netting	■Netting applies (default) OR Netting does not apply
Special Provisions Number of sheets attached: None Addendum(s):

IN WITNESS WHEREOF, the parties hereto have executed this Base Contract in duplicate.

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Richmond Energy LLC	PARTY NAME	[***]
By: /s/ Jonathan Maurer	SIGNATURE	By: [***]    By: [***]
Jonathan Maurer	PRINTED NAME	[***][***]
CO-CEO	TITLE	[***][***]

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General Terms and Conditions

Base Contract for Sale and Purchase of Natural Gas

SECTION 1.    PURPOSE AND PROCEDURES

1.1. These General Terms and Conditions are intended to facilitate purchase and sale transactions of Gas on a Firm or Interruptible basis. "Buyer" refers to the party receiving Gas and "Seller" refers to the party delivering Gas. The entire agreement between the parties shall be the Contract as defined in Section 2.9.

The parties have selected either the “Oral Transaction Procedure” or the “Written Transaction Procedure” as indicated on the Base Contract.

Oral Transaction Procedure:

1.2. The parties will use the following Transaction Confirmation procedure. Any Gas purchase and sale transaction may be effectuated in an EDI transmission or telephone conversation with the offer and acceptance constituting the agreement of the parties. The parties shall be legally bound from the time they so agree to transaction terms and may each rely thereon. Any such transaction shall be considered a “writing” and to have been “signed”. Notwithstanding the foregoing sentence, the parties agree that Confirming Party shall, and the other party may, confirm a telephonic transaction by sending the other party a Transaction Confirmation by facsimile, EDI or mutually agreeable electronic means within three Business Days of a transaction covered by this Section 1.2 (Oral Transaction Procedure) provided that the failure to send a Transaction Confirmation shall not invalidate the oral agreement of the parties. Confirming Party adopts its confirming letterhead, or the like, as its signature on any Transaction Confirmation as the identification and authentication of Confirming Party. If the Transaction Confirmation contains any provisions other than those relating to the commercial terms of the transaction (i.e., price, quantity, performance obligation, delivery point, period of delivery and/or transportation conditions), which modify or supplement the Base Contract or General Terms and Conditions of this Contract (e.g., arbitration or additional representations and warranties), such provisions shall not be deemed to be accepted pursuant to Section 1.3 but must be expressly agreed to by both parties; provided that the foregoing shall not

invalidate any transaction agreed to by the parties.

Written Transaction Procedure:

1.2. The parties will use the following Transaction Confirmation procedure. Should the parties come to an agreement regarding a Gas purchase and sale transaction for a particular Delivery Period, the Confirming Party shall, and the other party may, record that agreement on a Transaction Confirmation and communicate such Transaction Confirmation by facsimile, EDI or mutually agreeable electronic means, to the other party by the close of the Business Day following the date of agreement. The parties acknowledge that their agreement will not be binding until the exchange of nonconflicting Transaction Confirmations or the

passage of the Confirm Deadline without objection from the receiving party, as provided in Section 1.3.

1.3.If a sending party's Transaction Confirmation is materially different from the receiving party's understanding of the agreement referred to in Section 1.2, such receiving party shall notify the sending party via facsimile, EDI or mutually agreeable electronic means by the Confirm Deadline, unless such receiving party has previously sent a Transaction Confirmation to the sending party. The failure of the receiving party to so notify the sending party in writing by the Confirm Deadline constitutes the receiving party's agreement to the terms of the transaction described in the sending party's Transaction Confirmation. If there are any material differences between timely sent Transaction Confirmations governing the same transaction, then neither Transaction Confirmation shall be binding until or unless such differences are resolved including the use of any evidence that clearly resolves the differences in the Transaction Confirmations. In the event of a conflict among the terms of (i) a binding Transaction Confirmation pursuant to Section 1.2, (ii) the oral agreement of the parties which may be evidenced by a recorded conversation, where the parties have selected the Oral Transaction Procedure of the Base Contract,

(iii) the Base Contract, and (iv) these General Terms and Conditions, the terms of the documents shall govern in the priority listed in this sentence.

1.4.The parties agree that each party may electronically record all telephone conversations with respect to this Contract between their respective employees, without any special or further notice to the other party. Each party shall obtain any necessary consent of its agents and employees to such recording. Where the parties have selected the Oral Transaction Procedure in Section 1.2 of the Base Contract, the parties agree not to contest the validity or enforceability of telephonic recordings entered into in accordance with the requirements of this Base Contract.

SECTION 2.    DEFINITIONS

The terms set forth below shall have the meaning ascribed to them below. Other terms are also defined elsewhere in the Contract and shall have the meanings ascribed to them herein.

2.1.“Additional Event of Default” shall mean Transactional Cross Default or Indebtedness Cross Default, each as and if selected by the parties pursuant to the Base Contract.

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2.2.“Affiliate” shall mean, in relation to any person, any entity controlled, directly or indirectly, by the person, any entity that controls, directly or indirectly, the person or any entity directly or indirectly under common control with the person. For this purpose, “control” of any entity or person means ownership of at least 50 percent of the voting power of the entity or person.

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2.3.“Alternative Damages” shall mean such damages, expressed in dollars or dollars per MMBtu, as the parties shall agree upon in the Transaction Confirmation, in the event either Seller or Buyer fails to perform a Firm obligation to deliver Gas in the case of Seller or to receive Gas in the case of Buyer.

2.4."Base Contract" shall mean a contract executed by the parties that incorporates these General Terms and Conditions by reference; that specifies the agreed selections of provisions contained herein; and that sets forth other information required herein and any Special Provisions and addendum(s) as identified on page one.

2.5."British thermal unit" or "Btu" shall mean the International BTU, which is also called the Btu (IT).

2.6."Business Day(s)" shall mean Monday through Friday, excluding Federal Banking Holidays for transactions in the U.S.

2.7."Confirm Deadline" shall mean 5:00 p.m. in the receiving party's time zone on the second Business Day following the Day a Transaction Confirmation is received or, if applicable, on the Business Day agreed to by the parties in the Base Contract; provided, if the Transaction Confirmation is time stamped after 5:00 p.m. in the receiving party's time zone, it shall be deemed received at the opening of the next Business Day.

2.8."Confirming Party" shall mean the party designated in the Base Contract to prepare and forward Transaction Confirmations to the other party.

2.9."Contract" shall mean the legally-binding relationship established by (i) the Base Contract, (ii) any and all binding Transaction Confirmations and (iii) where the parties have selected the Oral Transaction Procedure in Section 1.2 of the Base Contract, any and all transactions that the parties have entered into through an EDI transmission or by telephone, but that have not been confirmed in a binding Transaction Confirmation, all of which shall form a single integrated agreement between the parties.

2.10."Contract Price" shall mean the amount expressed in U.S. Dollars per MMBtu to be paid by Buyer to Seller for the purchase of Gas as agreed to by the parties in a transaction.

2.11."Contract Quantity" shall mean the quantity of Gas to be delivered and taken as agreed to by the parties in a transaction.

2.12."Cover Standard", as referred to in Section 3.2, shall mean that if there is an unexcused failure to take or deliver any quantity of Gas pursuant to this Contract, then the performing party shall use commercially reasonable efforts to (i) if Buyer is the performing party, obtain Gas, (or an alternate fuel if elected by Buyer and replacement Gas is not available), or (ii) if Seller is the performing party, sell Gas, in either case, at a price reasonable for the delivery or production area, as applicable, consistent with: the amount of notice provided by the nonperforming party; the immediacy of the Buyer's Gas consumption needs or Seller's Gas sales requirements, as applicable; the quantities involved; and the anticipated length of failure by the nonperforming party.

2.13."Credit Support Obligation(s)” shall mean any obligation(s) to provide or establish credit support for, or on behalf of, a party to this Contract such as cash, an irrevocable standby letter of credit, a margin agreement, a prepayment, a security interest in an asset, guaranty, or other good and sufficient security of a continuing nature.

2.14."Day" shall mean a period of 24 consecutive hours, coextensive with a "day" as defined by the Receiving Transporter in a particular transaction.

2.15."Delivery Period" shall be the period during which deliveries are to be made as agreed to by the parties in a transaction.

2.16."Delivery Point(s)" shall mean such point(s) as are agreed to by the parties in a transaction.

2.17."EDI" shall mean an electronic data interchange pursuant to an agreement entered into by the parties, specifically relating to the communication of Transaction Confirmations under this Contract.

2.18."EFP" shall mean the purchase, sale or exchange of natural Gas as the "physical" side of an exchange for physical transaction involving gas futures contracts. EFP shall incorporate the meaning and remedies of "Firm", provided that a party’s excuse for nonperformance of its obligations to deliver or receive Gas will be governed by the rules of the relevant futures exchange regulated under the Commodity Exchange Act.

2.19."Firm" shall mean that either party may interrupt its performance without liability only to the extent that such performance is prevented for reasons of Force Majeure; provided, however, that during Force Majeure interruptions, the party invoking Force Majeure may be responsible for any Imbalance Charges as set forth in Section 4.3 related to its interruption after the nomination is made to the Transporter and until the change in deliveries and/or receipts is confirmed by the Transporter.

2.20."Gas" shall mean any mixture of hydrocarbons and noncombustible gases in a gaseous state consisting primarily of methane.

2.21.“Guarantor” shall mean any entity that has provided a guaranty of the obligations of a party hereunder.

2.22."Imbalance Charges" shall mean any fees, penalties, costs or charges (in cash or in kind) assessed by a Transporter for failure to satisfy the Transporter's balance and/or nomination requirements.

2.23.“Indebtedness Cross Default” shall mean if selected on the Base Contract by the parties with respect to a party, that it or its Guarantor, if any, experiences a default, or similar condition or event however therein defined, under one or more agreements or instruments, individually or collectively, relating to indebtedness (such indebtedness to include any obligation whether present or future, contingent or otherwise, as principal or surety or otherwise) for the payment or repayment of borrowed money in an aggregate amount greater than the threshold specified in the Base Contract with respect to such party or its Guarantor, if any, which results in such indebtedness becoming immediately due and payable.

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2.24."Interruptible" shall mean that either party may interrupt its performance at any time for any reason, whether or not caused by an event of Force Majeure, with no liability, except such interrupting party may be responsible for any Imbalance Charges as set

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forth in Section 4.3 related to its interruption after the nomination is made to the Transporter and until the change in deliveries and/or receipts is confirmed by Transporter.

2.25."MMBtu" shall mean one million British thermal units, which is equivalent to one dekatherm.

2.26."Month" shall mean the period beginning on the first Day of the calendar month and ending immediately prior to the commencement of the first Day of the next calendar month.

2.27."Payment Date" shall mean a date, as indicated on the Base Contract, on or before which payment is due Seller for Gas received by Buyer in the previous Month.

2.28."Receiving Transporter" shall mean the Transporter receiving Gas at a Delivery Point, or absent such receiving Transporter, the Transporter delivering Gas at a Delivery Point.

2.29."Scheduled Gas" shall mean the quantity of Gas confirmed by Transporter(s) for movement, transportation or management.

2.30.“Specified Transaction(s)” shall mean any other transaction or agreement between the parties for the purchase, sale or exchange of physical Gas, and any other transaction or agreement identified as a Specified Transaction under the Base Contract.

2.31."Spot Price " as referred to in Section 3.2 shall mean the price listed in the publication indicated on the Base Contract, under the listing applicable to the geographic location closest in proximity to the Delivery Point(s) for the relevant Day; provided, if there is no single price published for such location for such Day, but there is published a range of prices, then the Spot Price shall be the average of such high and low prices. If no price or range of prices is published for such Day, then the Spot Price shall be the average of the following: (i) the price (determined as stated above) for the first Day for which a price or range of prices is published that next precedes the relevant Day; and (ii) the price (determined as stated above) for the first Day for which a price or range of prices is published that next follows the relevant Day.

2.32."Transaction Confirmation" shall mean a document, similar to the form of Exhibit A, setting forth the terms of a transaction formed pursuant to Section 1 for a particular Delivery Period.

2.33.“Transactional Cross Default” shall mean if selected on the Base Contract by the parties with respect to a party, that it shall be in default, however therein defined, under any Specified Transaction.

2.34.“Termination Option” shall mean the option of either party to terminate a transaction in the event that the other party fails to perform a Firm obligation to deliver Gas in the case of Seller or to receive Gas in the case of Buyer for a designated number of days during a period as specified on the applicable Transaction Confirmation.

2.35."Transporter(s)" shall mean all Gas gathering or pipeline companies, or local distribution companies, acting in the capacity of a transporter, transporting Gas for Seller or Buyer upstream or downstream, respectively, of the Delivery Point pursuant to a particular transaction.

SECTION 3.    PERFORMANCE OBLIGATION

3.1.Seller agrees to sell and deliver, and Buyer agrees to receive and purchase, the Contract Quantity for a particular transaction in accordance with the terms of the Contract. Sales and purchases will be on a Firm or Interruptible basis, as agreed to by the parties in a transaction.

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The parties have selected either the “Cover Standard” or the “Spot Price Standard” as indicated on the Base Contract.

Cover Standard:

3.2. The sole and exclusive remedy of the parties in the event of a breach of a Firm obligation to deliver or receive Gas shall be recovery of the following: (i) in the event of a breach by Seller on any Day(s), payment by Seller to Buyer in an amount equal to the positive difference, if any, between the purchase price paid by Buyer utilizing the Cover Standard and the Contract Price, adjusted for commercially reasonable differences in transportation costs to or from the Delivery Point(s), multiplied by the difference between the Contract Quantity and the quantity actually delivered by Seller for such Day(s) excluding any quantity for which no replacement is available; or (ii) in the event of a breach by Buyer on any Day(s), payment by Buyer to Seller in the amount equal to the positive difference, if any, between the Contract Price and the price received by Seller utilizing the Cover Standard for the resale of such Gas, adjusted for commercially reasonable differences in transportation costs to or from the Delivery Point(s), multiplied by the difference between the Contract Quantity and the quantity actually taken by Buyer for such Day(s) excluding any quantity for which no sale is available; and (iii) in the event that Buyer has used commercially reasonable efforts to replace the Gas or Seller has used commercially reasonable efforts to sell the Gas to a third party, and no such replacement or sale is available for all or any portion of the Contract Quantity of Gas, then in addition to (i) or (ii) above, as applicable, the sole and exclusive remedy of the performing party with respect to the Gas not replaced or sold shall be an amount equal to any unfavorable difference between the Contract Price and the Spot Price, adjusted for such transportation to the applicable Delivery Point, multiplied by the quantity of such Gas not replaced or sold. Imbalance Charges shall not be recovered under this Section 3.2, but Seller and/or Buyer shall be responsible for Imbalance Charges, if any, as provided in Section 4.3. The amount of such unfavorable difference shall be payable five Business Days after presentation of the performing party’s invoice,

which shall set forth the basis upon which such amount was calculated.

Spot Price Standard:

3.2. The sole and exclusive remedy of the parties in the event of a breach of a Firm obligation to deliver or receive Gas shall be recovery of the following: (i) in the event of a breach by Seller on any Day(s), payment by Seller to Buyer in an amount equal to the difference between the Contract Quantity and the actual quantity delivered by Seller and received by Buyer for such Day(s),

multiplied by the positive difference, if any, obtained by subtracting the Contract Price from the Spot Price; or (ii) in the event of a

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breach by Buyer on any Day(s), payment by Buyer to Seller in an amount equal to the difference between the Contract Quantity and the actual quantity delivered by Seller and received by Buyer for such Day(s), multiplied by the positive difference, if any, obtained by subtracting the applicable Spot Price from the Contract Price. Imbalance Charges shall not be recovered under this Section 3.2, but Seller and/or Buyer shall be responsible for Imbalance Charges, if any, as provided in Section 4.3. The amount of such unfavorable difference shall be payable five Business Days after presentation of the performing party’s invoice, which

shall set forth the basis upon which such amount was calculated.

3.3.Notwithstanding Section 3.2, the parties may agree to Alternative Damages in a Transaction Confirmation executed in writing by both parties.

3.4.In addition to Sections 3.2 and 3.3, the parties may provide for a Termination Option in a Transaction Confirmation executed in writing by both parties. The Transaction Confirmation containing the Termination Option will designate the length of nonperformance triggering the Termination Option and the procedures for exercise thereof, how damages for nonperformance will be compensated, and how liquidation costs will be calculated.

SECTION 4.    TRANSPORTATION, NOMINATIONS, AND IMBALANCES

4.1.Seller shall have the sole responsibility for transporting the Gas to the Delivery Point(s). Buyer shall have the sole responsibility for transporting the Gas from the Delivery Point(s).

4.2.The parties shall coordinate their nomination activities, giving sufficient time to meet the deadlines of the affected Transporter(s). Each party shall give the other party timely prior Notice, sufficient to meet the requirements of all Transporter(s) involved in the transaction, of the quantities of Gas to be delivered and purchased each Day. Should either party become aware that actual deliveries at the Delivery Point(s) are greater or lesser than the Scheduled Gas, such party shall promptly notify the other party.

4.3.The parties shall use commercially reasonable efforts to avoid imposition of any Imbalance Charges. If Buyer or Seller receives an invoice from a Transporter that includes Imbalance Charges, the parties shall determine the validity as well as the cause of such Imbalance Charges. If the Imbalance Charges were incurred as a result of Buyer’s receipt of quantities of Gas greater than or less than the Scheduled Gas, then Buyer shall pay for such Imbalance Charges or reimburse Seller for such Imbalance Charges paid by Seller. If the Imbalance Charges were incurred as a result of Seller’s delivery of quantities of Gas greater than or less than the Scheduled Gas, then Seller shall pay for such Imbalance Charges or reimburse Buyer for such Imbalance Charges paid by Buyer.

SECTION 5.    QUALITY AND MEASUREMENT

All Gas delivered by Seller shall meet the pressure, quality and heat content requirements of the Receiving Transporter. The unit of quantity measurement for purposes of this Contract shall be one MMBtu dry. Measurement of Gas quantities hereunder shall be in accordance with the established procedures of the Receiving Transporter.

SECTION 6. TAXES

The parties have selected either “Buyer Pays At and After Delivery Point” or “Seller Pays Before and At Delivery Point” as indicated on the Base Contract.

Buyer Pays At and After Delivery Point:

Seller shall pay or cause to be paid all taxes, fees, levies, penalties, licenses or charges imposed by any government authority (“Taxes”) on or with respect to the Gas prior to the Delivery Point(s). Buyer shall pay or cause to be paid all Taxes on or with respect to the Gas at the Delivery Point(s) and all Taxes after the Delivery Point(s). If a party is required to remit or pay Taxes that are the other party’s responsibility hereunder, the party responsible for such Taxes shall promptly reimburse the other party for such Taxes. Any party entitled to an exemption from any such Taxes or charges shall furnish the other party any necessary documentation thereof.

Seller Pays Before and At Delivery Point:

Seller shall pay or cause to be paid all taxes, fees, levies, penalties, licenses or charges imposed by any government authority (“Taxes”) on or with respect to the Gas prior to the Delivery Point(s) and all Taxes at the Delivery Point(s). Buyer shall pay or cause to be paid all Taxes on or with respect to the Gas after the Delivery Point(s). If a party is required to remit or pay Taxes that are the other party’s responsibility hereunder, the party responsible for such Taxes shall promptly reimburse the other party for such Taxes. Any party entitled to an exemption from any such Taxes or charges shall furnish the other party any necessary documentation thereof.

SECTION 7.    BILLING, PAYMENT, AND AUDIT

7.1.Seller shall invoice Buyer for Gas delivered and received in the preceding Month and for any other applicable charges, providing supporting documentation acceptable in industry practice to support the amount charged. If the actual quantity delivered is not known by the billing date, billing will be prepared based on the quantity of Scheduled Gas. The invoiced quantity will then be adjusted to the actual quantity on the following Month's billing or as soon thereafter as actual delivery information is available.

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7.2.Buyer shall remit the amount due under Section 7.1 in the manner specified in the Base Contract, in immediately available funds, on or before the later of the Payment Date or 10 Days after receipt of the invoice by Buyer; provided that if the Payment Date is not a Business Day, payment is due on the next Business Day following that date. In the event any payments are due Buyer hereunder, payment to Buyer shall be made in accordance with this Section 7.2.

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7.3.In the event payments become due pursuant to Sections 3.2 or 3.3, the performing party may submit an invoice to the nonperforming party for an accelerated payment setting forth the basis upon which the invoiced amount was calculated. Payment from the nonperforming party will be due five Business Days after receipt of invoice.

7.4.If the invoiced party, in good faith, disputes the amount of any such invoice or any part thereof, such invoiced party will pay such amount as it concedes to be correct; provided, however, if the invoiced party disputes the amount due, it must provide supporting documentation acceptable in industry practice to support the amount paid or disputed without undue delay. In the event the parties are unable to resolve such dispute, either party may pursue any remedy available at law or in equity to enforce its rights pursuant to this Section.

7.5.If the invoiced party fails to remit the full amount payable when due, interest on the unpaid portion shall accrue from the date due until the date of payment at a rate equal to the lower of (i) the then-effective prime rate of interest published under "Money Rates" by The Wall Street Journal, plus two percent per annum; or (ii) the maximum applicable lawful interest rate.

7.6.A party shall have the right, at its own expense, upon reasonable Notice and at reasonable times, to examine and audit and to obtain copies of the relevant portion of the books, records, and telephone recordings of the other party only to the extent reasonably necessary to verify the accuracy of any statement, charge, payment, or computation made under the Contract. This right to examine, audit, and to obtain copies shall not be available with respect to proprietary information not directly relevant to transactions under this Contract. All invoices and billings shall be conclusively presumed final and accurate and all associated claims for under- or overpayments shall be deemed waived unless such invoices or billings are objected to in writing, with adequate explanation and/or documentation, within two years after the Month of Gas delivery. All retroactive adjustments under Section 7 shall be paid in full by the party owing payment within 30 Days of Notice and substantiation of such inaccuracy.

7.7.Unless the parties have elected on the Base Contract not to make this Section 7.7 applicable to this Contract, the parties shall net all undisputed amounts due and owing, and/or past due, arising under the Contract such that the party owing the greater amount shall make a single payment of the net amount to the other party in accordance with Section 7; provided that no payment required to be made pursuant to the terms of any Credit Support Obligation or pursuant to Section 7.3 shall be subject to netting under this Section. If the parties have executed a separate netting agreement, the terms and conditions therein shall prevail to the extent inconsistent herewith.

SECTION 8.    TITLE, WARRANTY, AND INDEMNITY

8.1.Unless otherwise specifically agreed, title to the Gas shall pass from Seller to Buyer at the Delivery Point(s). Seller shall have responsibility for and assume any liability with respect to the Gas prior to its delivery to Buyer at the specified Delivery Point(s). Buyer shall have responsibility for and assume any liability with respect to said Gas after its delivery to Buyer at the Delivery Point(s).

8.2.Seller warrants that it will have the right to convey and will transfer good and merchantable title to all Gas sold hereunder and delivered by it to Buyer, free and clear of all liens, encumbrances, and claims. EXCEPT AS PROVIDED IN THIS SECTION 8.2 AND IN SECTION 15.8, ALL OTHER WARRANTIES, EXPRESS OR IMPLIED, INCLUDING ANY WARRANTY OF MERCHANTABILITY OR OF FITNESS FOR ANY PARTICULAR PURPOSE, ARE DISCLAIMED.

8.3.Seller agrees to indemnify Buyer and save it harmless from all losses, liabilities or claims including reasonable attorneys' fees and costs of court ("Claims"), from any and all persons, arising from or out of claims of title, personal injury (including death) or property damage from said Gas or other charges thereon which attach before title passes to Buyer. Buyer agrees to indemnify Seller and save it harmless from all Claims, from any and all persons, arising from or out of claims regarding payment, personal injury (including death) or property damage from said Gas or other charges thereon which attach after title passes to Buyer.

8.4.The parties agree that the delivery of and the transfer of title to all Gas under this Contract shall take place within the Customs Territory of the United States (as defined in general note 2 of the Harmonized Tariff Schedule of the United States 19 U.S.C. §1202, General Notes, page 3); provided, however, that in the event Seller took title to the Gas outside the Customs Territory of the United States, Seller represents and warrants that it is the importer of record for all Gas entered and delivered into the United States, and shall be responsible for entry and entry summary filings as well as the payment of duties, taxes and fees, if any, and all applicable record keeping requirements.

8.5.Notwithstanding the other provisions of this Section 8, as between Seller and Buyer, Seller will be liable for all Claims to the extent that such arise from the failure of Gas delivered by Seller to meet the quality requirements of Section 5.

SECTION 9.    NOTICES

9.1.All Transaction Confirmations, invoices, payment instructions, and other communications made pursuant to the Base Contract ("Notices") shall be made to the addresses specified in writing by the respective parties from time to time.

9.2.All Notices required hereunder shall be in writing and may be sent by facsimile or mutually acceptable electronic means, a nationally recognized overnight courier service, first class mail or hand delivered.

9.3.Notice shall be given when received on a Business Day by the addressee. In the absence of proof of the actual receipt date, the following presumptions will apply. Notices sent by facsimile shall be deemed to have been received upon the sending party's receipt of its facsimile machine's confirmation of successful transmission. If the day on which such facsimile is received is not a Business Day or is after five p.m. on a Business Day, then such facsimile shall be deemed to have been received on the next

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following Business Day. Notice by overnight mail or courier shall be deemed to have been received on the next Business Day after it was sent or such earlier time as is confirmed by the receiving party. Notice via first class mail shall be considered delivered five Business Days after mailing.

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9.4.The party receiving a commercially acceptable Notice of change in payment instructions or other payment information shall not be obligated to implement such change until ten Business Days after receipt of such Notice.

SECTION 10.    FINANCIAL RESPONSIBILITY

10.1.If either party (“X”) has reasonable grounds for insecurity regarding the performance of any obligation under this Contract (whether or not then due) by the other party (“Y”) (including, without limitation, the occurrence of a material change in the creditworthiness of Y or its Guarantor, if applicable), X may demand Adequate Assurance of Performance. “Adequate Assurance of Performance” shall mean sufficient security in the form, amount, for a term, and from an issuer, all as reasonably acceptable to X, including, but not limited to cash, a standby irrevocable letter of credit, a prepayment, a security interest in an asset or guaranty. Y hereby grants to X a continuing first priority security interest in, lien on, and right of setoff against all Adequate Assurance of Performance in the form of cash transferred by Y to X pursuant to this Section 10.1. Upon the return by X to Y of such Adequate Assurance of Performance, the security interest and lien granted hereunder on that Adequate Assurance of Performance shall be released automatically and, to the extent possible, without any further action by either party.

10.2.In the event (each an "Event of Default") either party (the "Defaulting Party") or its Guarantor shall: (i) make an assignment or any general arrangement for the benefit of creditors; (ii) file a petition or otherwise commence, authorize, or acquiesce in the commencement of a proceeding or case under any bankruptcy or similar law for the protection of creditors or have such petition filed or proceeding commenced against it; (iii) otherwise become bankrupt or insolvent (however evidenced); (iv) be unable to pay its debts as they fall due; (v) have a receiver, provisional liquidator, conservator, custodian, trustee or other similar official appointed with respect to it or substantially all of its assets; (vi) fail to perform any obligation to the other party with respect to any Credit Support Obligations relating to the Contract; (vii) fail to give Adequate Assurance of Performance under Section 10.1 within 48 hours but at least one Business Day of a written request by the other party; (viii) not have paid any amount due the other party hereunder on or before the second Business Day following written Notice that such payment is due; or ix) be the affected party with respect to any Additional Event of Default; then the other party (the "Non-Defaulting Party") shall have the right, at its sole election, to immediately withhold and/or suspend deliveries or payments upon Notice and/or to terminate and liquidate the transactions under the Contract, in the manner provided in Section 10.3, in addition to any and all other remedies available hereunder.

10.3.If an Event of Default has occurred and is continuing, the Non-Defaulting Party shall have the right, by Notice to the Defaulting Party, to designate a Day, no earlier than the Day such Notice is given and no later than 20 Days after such Notice is given, as an early termination date (the “Early Termination Date”) for the liquidation and termination pursuant to Section 10.3.1 of all transactions under the Contract, each a “Terminated Transaction”. On the Early Termination Date, all transactions will terminate, other than those transactions, if any, that may not be liquidated and terminated under applicable law (“Excluded Transactions”), which Excluded Transactions must be liquidated and terminated as soon thereafter as is legally permissible, and upon termination shall be a Terminated Transaction and be valued consistent with Section 10.3.1 below. With respect to each Excluded Transaction, its actual termination date shall be the Early Termination Date for purposes of Section 10.3.1.

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The parties have selected either “Early Termination Damages Apply” or “Early Termination Damages Do Not Apply” as indicated on the Base Contract.

Early Termination Damages Apply:

10.3.1. As of the Early Termination Date, the Non-Defaulting Party shall determine, in good faith and in a commercially reasonable manner, (i) the amount owed (whether or not then due) by each party with respect to all Gas delivered and received between the parties under Terminated Transactions and Excluded Transactions on and before the Early Termination Date and all other applicable charges relating to such deliveries and receipts (including without limitation any amounts owed under Section 3.2), for which payment has not yet been made by the party that owes such payment under this Contract and (ii) the Market Value, as defined below, of each Terminated Transaction. The Non-Defaulting Party shall (x) liquidate and accelerate each Terminated Transaction at its Market Value, so that each amount equal to the difference between such Market Value and the Contract Value, as defined below, of such Terminated Transaction(s) shall be due to the Buyer under the Terminated Transaction(s) if such Market Value exceeds the Contract Value and to the Seller if the opposite is the case; and (y) where appropriate, discount each amount then due under clause (x) above to present value in a commercially reasonable manner as of the Early Termination Date (to take account of the period between the date of liquidation and the date on which such amount would have otherwise been due pursuant to the relevant Terminated Transactions).

For purposes of this Section 10.3.1, “Contract Value” means the amount of Gas remaining to be delivered or purchased under a transaction multiplied by the Contract Price, and “Market Value” means the amount of Gas remaining to be delivered or purchased under a transaction multiplied by the market price for a similar transaction at the Delivery Point determined by the Non-Defaulting Party in a commercially reasonable manner. To ascertain the Market Value, the Non-Defaulting Party may consider, among other valuations, any or all of the settlement prices of NYMEX Gas futures contracts, quotations from leading dealers in energy swap contracts or physical gas trading markets, similar sales or purchases and any other bona fide third-party offers, all adjusted for the length of the term and differences in transportation costs. A party shall not be required to enter into a replacement transaction(s) in order to determine the Market Value. Any extension(s) of the term of a transaction to which parties are not bound as of the Early Termination Date (including but not limited to “evergreen provisions”) shall not be considered in determining Contract Values and Market Values. For the avoidance of doubt, any option pursuant to which one party has the right to extend

the term of a transaction shall be considered in determining Contract Values and Market Values. The rate of interest used in calculating net present value shall be determined by the Non-Defaulting Party in a commercially reasonable manner.

Early Termination Damages Do Not Apply:

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10.3.1. As of the Early Termination Date, the Non-Defaulting Party shall determine, in good faith and in a commercially reasonable manner, the amount owed (whether or not then due) by each party with respect to all Gas delivered and received between the parties under Terminated Transactions and Excluded Transactions on and before the Early Termination Date and all other applicable charges relating to such deliveries and receipts (including without limitation any amounts owed under Section

3.2), for which payment has not yet been made by the party that owes such payment under this Contract.

The parties have selected either “Other Agreement Setoffs Apply” or “Other Agreement Setoffs Do Not Apply” as indicated on the Base Contract.

Other Agreement Setoffs Apply:

Bilateral Setoff Option:

10.3.2. The Non-Defaulting Party shall net or aggregate, as appropriate, any and all amounts owing between the parties under Section 10.3.1, so that all such amounts are netted or aggregated to a single liquidated amount payable by one party to the other (the “Net Settlement Amount”). At its sole option and without prior Notice to the Defaulting Party, the Non-Defaulting Party is hereby authorized to setoff any Net Settlement Amount against (i) any margin or other collateral held by a party in connection with any Credit Support Obligation relating to the Contract; and (ii) any amount(s) (including any excess cash margin or excess cash collateral) owed or held by the party that is entitled to the Net Settlement Amount under any other agreement or arrangement between the parties.

Triangular Setoff Option:

10.3.2. The Non-Defaulting Party shall net or aggregate, as appropriate, any and all amounts owing between the parties under Section 10.3.1, so that all such amounts are netted or aggregated to a single liquidated amount payable by one party to the other (the “Net Settlement Amount”). At its sole option, and without prior Notice to the Defaulting Party, the Non-Defaulting Party is hereby authorized to setoff (i) any Net Settlement Amount against any margin or other collateral held by a party in connection with any Credit Support Obligation relating to the Contract; (ii) any Net Settlement Amount against any amount(s) (including any excess cash margin or excess cash collateral) owed by or to a party under any other agreement or arrangement between the parties; (iii) any Net Settlement Amount owed to the Non-Defaulting Party against any amount(s) (including any excess cash margin or excess cash collateral) owed by the Non-Defaulting Party or its Affiliates to the Defaulting Party under any other agreement or arrangement; (iv) any Net Settlement Amount owed to the Defaulting Party against any amount(s) (including any excess cash margin or excess cash collateral) owed by the Defaulting Party to the Non-Defaulting Party or its Affiliates under any other agreement or arrangement; and/or (v) any Net Settlement Amount owed to the Defaulting Party against any amount(s) (including any excess cash margin or excess cash collateral) owed by the Defaulting Party or its Affiliates to the Non-Defaulting

Party under any other agreement or arrangement.

Other Agreement Setoffs Do Not Apply:

10.3.2. The Non-Defaulting Party shall net or aggregate, as appropriate, any and all amounts owing between the parties under Section 10.3.1, so that all such amounts are netted or aggregated to a single liquidated amount payable by one party to the other (the “Net Settlement Amount”). At its sole option and without prior Notice to the Defaulting Party, the Non-Defaulting Party

may setoff any Net Settlement Amount against any margin or other collateral held by a party in connection with any Credit Support Obligation relating to the Contract.

10.3.3. If any obligation that is to be included in any netting, aggregation or setoff pursuant to Section 10.3.2 is unascertained, the Non-Defaulting Party may in good faith estimate that obligation and net, aggregate or setoff, as applicable, in respect of the estimate, subject to the Non-Defaulting Party accounting to the Defaulting Party when the obligation is ascertained. Any amount not then due which is included in any netting, aggregation or setoff pursuant to Section 10.3.2 shall be discounted to net present value in a commercially reasonable manner determined by the Non-Defaulting Party.

10.4.As soon as practicable after a liquidation, Notice shall be given by the Non-Defaulting Party to the Defaulting Party of the Net Settlement Amount, and whether the Net Settlement Amount is due to or due from the Non-Defaulting Party. The Notice shall include a written statement explaining in reasonable detail the calculation of the Net Settlement Amount, provided that failure to give such Notice shall not affect the validity or enforceability of the liquidation or give rise to any claim by the Defaulting Party against the Non- Defaulting Party. The Net Settlement Amount as well as any setoffs applied against such amount pursuant to Section 10.3. 2, shall be paid by the close of business on the second Business Day following such Notice, which date shall not be earlier than the Early Termination Date. Interest on any unpaid portion of the Net Settlement Amount as adjusted by setoffs, shall accrue from the date due until the date of payment at a rate equal to the lower of (i) the then-effective prime rate of interest published under "Money Rates" by The Wall Street Journal, plus two percent per annum; or (ii) the maximum applicable lawful interest rate.

10.5.The parties agree that the transactions hereunder constitute a "forward contract" within the meaning of the United States Bankruptcy Code and that Buyer and Seller are each "forward contract merchants" within the meaning of the United States Bankruptcy Code.

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10.6.The Non-Defaulting Party's remedies under this Section 10 are the sole and exclusive remedies of the Non-Defaulting Party with respect to the occurrence of any Early Termination Date. Each party reserves to itself all other rights, setoffs, counterclaims and other defenses that it is or may be entitled to arising from the Contract.

10.7.With respect to this Section 10, if the parties have executed a separate netting agreement with close-out netting provisions, the terms and conditions therein shall prevail to the extent inconsistent herewith.

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SECTION 11.    FORCE MAJEURE

11.1.Except with regard to a party's obligation to make payment(s) due under Section 7, Section 10.4, and Imbalance Charges under Section 4, neither party shall be liable to the other for failure to perform a Firm obligation, to the extent such failure was caused by Force Majeure. The term "Force Majeure" as employed herein means any cause not reasonably within the control of the party claiming suspension, as further defined in Section 11.2.

11.2.Force Majeure shall include, but not be limited to, the following: (i) physical events such as acts of God, landslides, lightning, earthquakes, fires, storms or storm warnings, such as hurricanes, which result in evacuation of the affected area, floods, washouts, explosions, breakage or accident or necessity of repairs to machinery or equipment or lines of pipe; (ii) weather related events affecting an entire geographic region, such as low temperatures which cause freezing or failure of wells or lines of pipe;

(iii) interruption and/or curtailment of Firm transportation and/or storage by Transporters; (iv) acts of others such as strikes, lockouts or other industrial disturbances, riots, sabotage, insurrections or wars, or acts of terror; and (v) governmental actions such as necessity for compliance with any court order, law, statute, ordinance, regulation, or policy having the effect of law promulgated by a governmental authority having jurisdiction. Seller and Buyer shall make reasonable efforts to avoid the adverse impacts of a Force Majeure and to resolve the event or occurrence once it has occurred in order to resume performance.

11.3.Neither party shall be entitled to the benefit of the provisions of Force Majeure to the extent performance is affected by any or all of the following circumstances: (i) the curtailment of interruptible or secondary Firm transportation unless primary, in-path, Firm transportation is also curtailed; (ii) the party claiming excuse failed to remedy the condition and to resume the performance of such covenants or obligations with reasonable dispatch; or (iii) economic hardship, to include, without limitation, Seller’s ability to sell Gas at a higher or more advantageous price than the Contract Price, Buyer’s ability to purchase Gas at a lower or more advantageous price than the Contract Price, or a regulatory agency disallowing, in whole or in part, the pass through of costs resulting from this Contract; (iv) the loss of Buyer’s market(s) or Buyer’s inability to use or resell Gas purchased hereunder, except, in either case, as provided in Section 11.2; or (v) the loss or failure of Seller’s gas supply or depletion of reserves, except, in either case, as provided in Section 11.2. The party claiming Force Majeure shall not be excused from its responsibility for Imbalance Charges.

11.4.Notwithstanding anything to the contrary herein, the parties agree that the settlement of strikes, lockouts or other industrial disturbances shall be within the sole discretion of the party experiencing such disturbance.

11.5.The party whose performance is prevented by Force Majeure must provide Notice to the other party. Initial Notice may be given orally; however, written Notice with reasonably full particulars of the event or occurrence is required as soon as reasonably possible. Upon providing written Notice of Force Majeure to the other party, the affected party will be relieved of its obligation, from the onset of the Force Majeure event, to make or accept delivery of Gas, as applicable, to the extent and for the duration of Force Majeure, and neither party shall be deemed to have failed in such obligations to the other during such occurrence or event.

11.6.Notwithstanding Sections 11.2 and 11.3, the parties may agree to alternative Force Majeure provisions in a Transaction Confirmation executed in writing by both parties.

SECTION 12.    TERM

This Contract may be terminated on 30 Day’s written Notice, but shall remain in effect until the expiration of the latest Delivery Period of any transaction(s). The rights of either party pursuant to Section 7.6, Section 10, Section 13, the obligations to make payment hereunder, and the obligation of either party to indemnify the other, pursuant hereto shall survive the termination of the Base Contract or any transaction.

SECTION 13. LIMITATIONS

FOR BREACH OF ANY PROVISION FOR WHICH AN EXPRESS REMEDY OR MEASURE OF DAMAGES IS PROVIDED, SUCH EXPRESS REMEDY OR MEASURE OF DAMAGES SHALL BE THE SOLE AND EXCLUSIVE REMEDY. A PARTY’S LIABILITY HEREUNDER SHALL BE LIMITED AS SET FORTH IN SUCH PROVISION, AND ALL OTHER REMEDIES OR DAMAGES AT LAW OR IN EQUITY ARE WAIVED. IF NO REMEDY OR MEASURE OF DAMAGES IS EXPRESSLY PROVIDED HEREIN OR IN A TRANSACTION, A PARTY’S LIABILITY SHALL BE LIMITED TO DIRECT ACTUAL DAMAGES ONLY. SUCH DIRECT ACTUAL DAMAGES SHALL BE THE SOLE AND EXCLUSIVE REMEDY, AND ALL OTHER REMEDIES OR DAMAGES AT LAW OR IN EQUITY ARE WAIVED. UNLESS EXPRESSLY HEREIN PROVIDED, NEITHER PARTY SHALL BE LIABLE FOR CONSEQUENTIAL, INCIDENTAL, PUNITIVE, EXEMPLARY OR INDIRECT DAMAGES, LOST PROFITS OR OTHER BUSINESS INTERRUPTION DAMAGES, BY STATUTE, IN TORT OR CONTRACT, UNDER ANY INDEMNITY PROVISION OR OTHERWISE. IT IS THE INTENT OF THE PARTIES THAT THE LIMITATIONS HEREIN IMPOSED ON REMEDIES AND THE MEASURE OF DAMAGES BE WITHOUT REGARD TO THE CAUSE OR CAUSES RELATED THERETO, INCLUDING THE NEGLIGENCE OF ANY PARTY, WHETHER SUCH NEGLIGENCE BE SOLE, JOINT OR CONCURRENT, OR ACTIVE OR PASSIVE. TO THE EXTENT ANY DAMAGES REQUIRED TO BE PAID HEREUNDER ARE LIQUIDATED, THE PARTIES ACKNOWLEDGE THAT THE DAMAGES ARE DIFFICULT OR IMPOSSIBLE TO DETERMINE, OR OTHERWISE OBTAINING AN ADEQUATE REMEDY IS INCONVENIENT AND THE DAMAGES CALCULATED HEREUNDER CONSTITUTE A REASONABLE APPROXIMATION OF THE HARM OR LOSS.

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SECTION 14. MARKET DISRUPTION

If a Market Disruption Event has occurred then the parties shall negotiate in good faith to agree on a replacement price for the Floating Price (or on a method for determining a replacement price for the Floating Price) for the affected Day, and if the parties have not so agreed on or before the second Business Day following the affected Day then the replacement price for the Floating Price shall be determined within the next two following Business Days with each party obtaining, in good faith and from non-affiliated market participants in the relevant market, two quotes for prices of Gas for the affected Day of a similar quality and quantity in the geographical location closest in proximity to the Delivery Point and averaging the four quotes. If either party fails to provide two quotes then the average of the other party’s two quotes shall determine the replacement price for the Floating Price. "Floating Price" means the price or a factor of the price agreed to in the transaction as being based upon a specified index. "Market Disruption Event" means, with respect to an index specified for a transaction, any of the following events: (a) the failure of the index to announce or publish information necessary for determining the Floating Price; (b) the failure of trading to commence or the permanent discontinuation or material suspension of trading on the exchange or market acting as the index; (c) the temporary or permanent discontinuance or unavailability of the index; (d) the temporary or permanent closing of any exchange acting as the index; or (e) both parties agree that a material change in the formula for or the method of determining the Floating Price has occurred. For the purposes of the calculation of a replacement price for the Floating Price, all numbers shall be rounded to three decimal places. If the fourth decimal number is five or greater, then the third decimal number shall be increased by one and if the fourth decimal number is less than five, then the third decimal number shall remain unchanged.

SECTION 15. MISCELLANEOUS

15.1.This Contract shall be binding upon and inure to the benefit of the successors, assigns, personal representatives, and heirs of the respective parties hereto, and the covenants, conditions, rights and obligations of this Contract shall run for the full term of this Contract. No assignment of this Contract, in whole or in part, will be made without the prior written consent of the non-assigning party (and shall not relieve the assigning party from liability hereunder), which consent will not be unreasonably withheld or delayed; provided, either party may

(i) transfer, sell, pledge, encumber, or assign this Contract or the accounts, revenues, or proceeds hereof in connection with any financing or other financial arrangements, or (ii) transfer its interest to any parent or Affiliate by assignment, merger or otherwise without the prior approval of the other party. Upon any such assignment, transfer and assumption, the transferor shall remain principally liable for and shall not be relieved of or discharged from any obligations hereunder.

15.2.If any provision in this Contract is determined to be invalid, void or unenforceable by any court having jurisdiction, such determination shall not invalidate, void, or make unenforceable any other provision, agreement or covenant of this Contract.

15.3.No waiver of any breach of this Contract shall be held to be a waiver of any other or subsequent breach.

15.4.This Contract sets forth all understandings between the parties respecting each transaction subject hereto, and any prior contracts, understandings and representations, whether oral or written, relating to such transactions are merged into and superseded by this Contract and any effective transaction(s). This Contract may be amended only by a writing executed by both parties.

15.5.The interpretation and performance of this Contract shall be governed by the laws of the jurisdiction as indicated on the Base Contract, excluding, however, any conflict of laws rule which would apply the law of another jurisdiction.

15.6.This Contract and all provisions herein will be subject to all applicable and valid statutes, rules, orders and regulations of any governmental authority having jurisdiction over the parties, their facilities, or Gas supply, this Contract or transaction or any provisions thereof.

15.7.There is no third party beneficiary to this Contract.

15.8.Each party to this Contract represents and warrants that it has full and complete authority to enter into and perform this Contract. Each person who executes this Contract on behalf of either party represents and warrants that it has full and complete authority to do so and that such party will be bound thereby.

15.9.The headings and subheadings contained in this Contract are used solely for convenience and do not constitute a part of this Contract between the parties and shall not be used to construe or interpret the provisions of this Contract.

15.10.Unless the parties have elected on the Base Contract not to make this Section 15.10 applicable to this Contract, neither party shall disclose directly or indirectly without the prior written consent of the other party the terms of any transaction to a third party (other than the employees, lenders, royalty owners, counsel, accountants and other agents of the party, or prospective purchasers of all or substantially all of a party’s assets or of any rights under this Contract, provided such persons shall have agreed to keep such terms confidential) except (i) in order to comply with any applicable law, order, regulation, or exchange rule, (ii) to the extent necessary for the enforcement of this Contract

, (iii) to the extent necessary to implement any transaction, (iv) to the extent necessary to comply with a regulatory agency’s reporting requirements including but not limited to gas cost recovery proceedings; or (v) to the extent such information is delivered to such third party for the sole purpose of calculating a published index. Each party shall notify the other party of any proceeding of which it is aware which may result in disclosure of the terms of any transaction (other than as permitted hereunder) and use reasonable efforts to prevent or limit the disclosure. The existence of this Contract is not subject to this confidentiality obligation. Subject to Section 13, the parties shall be entitled to all remedies available at law or in equity to enforce, or seek relief in connection with this confidentiality obligation. The terms of any transaction hereunder shall be kept confidential by the parties hereto for one year from the expiration of the transaction.

In the event that disclosure is required by a governmental body or applicable law, the party subject to such requirement may disclose the material terms of this Contract to the extent so required, but shall promptly notify the other party, prior to disclosure ,

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and shall cooperate (consistent with the disclosing party’s legal obligations) with the other party’s efforts to obtain protective orders or similar restraints with respect to such disclosure at the expense of the other party.

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15.11.The parties may agree to dispute resolution procedures in Special Provisions attached to the Base Contract or in a Transaction Confirmation executed in writing by both parties

15.12.Any original executed Base Contract, Transaction Confirmation or other related document may be digitally copied, photocopied, or stored on computer tapes and disks (the “Imaged Agreement”). The Imaged Agreement, if introduced as evidence on paper, the Transaction Confirmation, if introduced as evidence in automated facsimile form, the recording, if introduced as evidence in its original form, and all computer records of the foregoing, if introduced as evidence in printed format, in any judicial, arbitration, mediation or administrative proceedings will be admissible as between the parties to the same extent and under the same conditions as other business records originated and maintained in documentary form. Neither Party shall object to the admissibility of the recording, the Transaction Confirmation, or the Imaged Agreement on the basis that such were not originated or maintained in documentary form. However, nothing herein shall be construed as a waiver of any other objection to the admissibility of such evidence.

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TRANSACTION CONFIRMATION    EXHIBIT A FOR IMMEDIATE DELIVERY

Letterhead/Logo		Date: , Transaction Confirmation #:
This Transaction Confirmation is subject to the Base Contract between Seller and Buyer dated . The terms of this Transaction Confirmation are binding unless disputed in writing within 2 Business Days of receipt unless otherwise specified in the Base Contract.
SELLER: Attn: Phone: Fax: Base Contract No. Transporter: Transporter Contract Number:	BUYER: Attn: Phone: Fax: Base Contract No. Transporter: Transporter Contract Number:
Contract Price: $/MMBtu or
Delivery Period: Begin: ,     End: ,
Performance Obligation and Contract Quantity: (Select One) Firm (Fixed Quantity):    Firm (Variable Quantity):    Interruptible: MMBtus/day    MMBtus/day Minimum    Up to MMBtus/day EFP    MMBtus/day Maximum subject to Section 4.2. at election of Buyer or    Seller
Delivery Point(s): (If a pooling point is used, list a specific geographic and pipeline location):
Special Conditions:
Seller: By: Title: Date:	Buyer: By: Title: Date:

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EX-31.1

EXHIBIT 31.1

CERTIFICATION 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

I, Adam Comora, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of OPAL Fuels Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 14, 2023	By:	/s/ Adam Comora
		Co-Chief Executive Officer
		(Co-Principal Executive Officer)

EX-31.2

EXHIBIT 31.2

CERTIFICATION 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

I, Jonathan Maurer, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of OPAL Fuels Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 14, 2023	By:	/s/ Jonathan Maurer
		Co-Chief Executive Officer
		(Co-Principal Executive Officer)

EX-31.3

EXHIBIT 31.3

CERTIFICATION 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

I, Ann Anthony, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of OPAL Fuels Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 14, 2023	By:	/s/ Ann Anthony
		Chief Financial Officer
		(Principal Financial Officer)

EX-32.1

EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of OPAL Fuels Inc. (the “Company”) on Form 10-Q for the three months ended September 30, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Adam Comora, Co-Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: November 14, 2023
	/s/ Adam Comora
	Name: Adam Comora
	Title: Co-Chief Executive Officer
	(Co-Principal Executive Officer)

EX-32.2

EXHIBIT 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of OPAL Fuels Inc. (the “Company”) on Form 10-Q for the three months ended September 30, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Jonathan Maurer, Co-Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: November 14, 2023
	/s/ Jonathan Maurer
	Name: Jonathan Maurer
	Title: Co-Chief Executive Officer
	(Co-Principal Executive Officer)

EX-32.3

EXHIBIT 32.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of OPAL Fuels Inc. (the “Company”) on Form 10-Q for the three months ended September 30, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Ann Anthony, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to my knowledge:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: November 14, 2023
	/s/ Ann Anthony
	Name: Ann Anthony
	Title: Chief Financial Officer
	(Principal Financial Officer)

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Cover Page - shares	9 Months Ended
	Sep. 30, 2023	Nov. 11, 2023
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2023
Document Transition Report	false
Entity File Number	001-40272
Entity Registrant Name	OPAL FUELS INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	98-1578357
Entity Address, Address Line One	One North Lexington Avenue
Entity Address, Address Line Two	Suite 1450
Entity Address, City or Town	White Plains
Entity Address, State or Province	NY
Entity Address, Postal Zip Code	10601
City Area Code	914
Local Phone Number	705-4000
Title of 12(b) Security	Class A Common Stock, par value $0.0001 per share
Trading Symbol	OPAL
Security Exchange Name	NASDAQ
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	true
Entity Ex Transition Period	false
Entity Shell Company	false
Entity Central Index Key	0001842279
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Class A common stock
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		27,975,260
Class D common stock
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		144,399,037

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CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents (includes $1,302 and $12,506 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	$ 15,000	$ 40,394
Accounts receivable	31,000	31,083
Restricted cash - current (includes $1,232 and $6,971 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	1,232	32,402
Short term investments	18,028	64,976
Fuel tax credits receivable	4,386	4,144
Contract assets	14,404	9,771
Parts inventory	11,897	7,311
Environmental credits held for sale (includes $29 and $0 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	4,339	1,674
Prepaid expense and other current assets (includes $193 and $415 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	5,013	7,625
Derivative financial assets, current portion	486	182
Total current assets	105,785	211,983
Capital spares	3,079	3,443
Property, plant, and equipment, net (includes $26,684 and $73,140 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	303,690	297,323
Operating right-of-use assets	12,368	11,744
Investment in other entities	199,466	51,765
Note receivable - variable fee component	2,178	1,942
Derivative financial assets, non-current portion	117	954
Deferred financing costs	0	3,013
Other long-term assets	2,108	1,489
Intangible assets, net	1,700	2,167
Restricted cash - non-current (includes $2,843 and $2,923 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	5,356	4,425
Goodwill	54,608	54,608
Total assets	690,455	644,856
Current liabilities:
Fuel tax credits payable	3,720	3,320
Accrued payroll	8,313	8,979
Accrued capital expenses (includes $0 and $7,821 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	7,355	11,922
Accrued expenses and other current liabilities (includes $602 and $646 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	13,779	9,573
Contract liabilities	7,429	8,013
OPAL Term Loan, current portion	0	27,732
Sunoma Loan, current portion (includes $1,739 and $380 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	1,739	380
Convertible Note Payable	0	28,528
Municipality Loan	0	76
Derivative financial liability, current portion	0	4,596
Operating lease liabilities - current portion	625	630
Other current liabilities	0	1,085
Asset retirement obligation, current portion	1,296	1,296
Total current liabilities	56,930	152,905
Asset retirement obligation, non-current portion	5,267	4,960
OPAL Term Loan, net of debt issuance costs	153,626	66,600
Sunoma Loan, net of debt issuance costs (includes $20,402 and $21,712 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	20,402	21,712
Operating lease liabilities - non-current portion	11,899	11,245
Earn out liabilities	4,291	8,790
Other long-term liabilities	1,163	825
Total liabilities	253,578	267,037
Commitments and contingencies
Stockholders' deficit
Additional paid-in capital	0	0
Accumulated deficit	(841,417)	(800,813)
Accumulated other comprehensive income	70	195
Class A common stock in treasury, at cost; 1,635,783 and 0 shares at September 30, 2023 and December 31, 2022, respectively	(11,614)	0
Total Stockholders' deficit attributable to the Company	(852,944)	(800,601)
Non-redeemable non-controlling interests	884	26,445
Total Stockholders' deficit	(852,060)	(774,156)
Total liabilities, Redeemable preferred non-controlling interests, Redeemable non-controlling interests and Stockholders' deficit	690,455	644,856
Primary Beneficiary
Current assets:
Cash and cash equivalents (includes $1,302 and $12,506 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	1,302	12,506
Accounts receivable	79	966
Restricted cash - current (includes $1,232 and $6,971 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	1,232	6,971
Environmental credits held for sale (includes $29 and $0 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	29	0
Prepaid expense and other current assets (includes $193 and $415 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	193	415
Total current assets	2,835	20,858
Property, plant, and equipment, net (includes $26,684 and $73,140 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	26,684	73,140
Restricted cash - non-current (includes $2,843 and $2,923 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	2,843	2,923
Total assets	32,362	96,921
Current liabilities:
Accrued capital expenses (includes $0 and $7,821 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	0	7,821
Accrued expenses and other current liabilities (includes $602 and $646 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	602	646
Sunoma Loan, current portion (includes $1,739 and $380 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	1,739	380
Total current liabilities	3,979	14,176
Sunoma Loan, net of debt issuance costs (includes $20,402 and $21,712 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)	20,402	21,712
Total liabilities	24,381	35,888
Stockholders' deficit
Total Stockholders' deficit attributable to the Company	7,097	34,588
Non-redeemable non-controlling interests	884	26,445
Total Stockholders' deficit	7,981	61,033
Total liabilities, Redeemable preferred non-controlling interests, Redeemable non-controlling interests and Stockholders' deficit	32,362	96,921
Senior Secured Credit Facility, term loan
Current liabilities:
Senior Secured Credit Facility - term loan, current portion, net of debt issuance costs	0	15,250
Senior Secured Credit Facility - working capital facility, current portion	0	15,250
Senior Secured Credit Facility, working capital facility
Current liabilities:
Senior Secured Credit Facility - term loan, current portion, net of debt issuance costs	0	7,500
Senior Secured Credit Facility - working capital facility, current portion	0	7,500
Related Party
Current assets:
Accounts receivable, related party	0	12,421
Current liabilities:
Accounts payable	1,365	1,346
Related Party | Primary Beneficiary
Current liabilities:
Accounts payable	1,035	433
Nonrelated Party
Current assets:
Accounts receivable		31,083
Current liabilities:
Accounts payable	11,309	22,679
Nonrelated Party | Primary Beneficiary
Current liabilities:
Accounts payable	603	4,896
Redeemable preferred non-controlling interests
Current liabilities:
Redeemable non-controlling interests	130,000	138,142
Redeemable non-controlling interests
Current liabilities:
Redeemable non-controlling interests	1,158,937	1,013,833
Class A common stock
Stockholders' deficit
Common stock	3	3
Class B common stock
Stockholders' deficit
Common stock	0	0
Class C common stock
Stockholders' deficit
Common stock	0	0
Class D common stock
Stockholders' deficit
Common stock	$ 14	$ 14

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CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) $ in Thousands	Sep. 30, 2023 USD ($) $ / shares shares
Cash and cash equivalents	$ 15,000
Accounts receivable, net	31,000
Restricted cash - current	1,232
Environmental credits held for sale	4,339
Prepaid expenses and other current assets	5,013
Property, plant and equipment, net	303,690
Restricted cash, non-current	5,356
Accrued capital expenses	7,355
Accrued expenses and other current liabilities	13,779
Sunoma Loan- current portion	1,739
Sunoma Loan, net of debt issuance costs	$ 20,402
Class A common stock, in treasury, at cost (in shares) | shares	1,635,783
Nonrelated Party
Accounts payable	$ 11,309
Related Party
Accounts payable	1,365
Primary Beneficiary
Cash and cash equivalents	1,302
Accounts receivable, net	79
Restricted cash - current	1,232
Environmental credits held for sale	29
Prepaid expenses and other current assets	193
Property, plant and equipment, net	26,684
Restricted cash, non-current	2,843
Accrued capital expenses	0
Accrued expenses and other current liabilities	602
Sunoma Loan- current portion	1,739
Sunoma Loan, net of debt issuance costs	20,402
Primary Beneficiary | Nonrelated Party
Accounts payable	603
Primary Beneficiary | Related Party
Accounts payable	$ 1,035
Class A common stock
Common stock, par value (in dollars per share) | $ / shares	$ 0.0001
Common stock, shares authorized (in shares) | shares	340,000,000
Common stock, shares issued (in shares) | shares	29,332,333
Common stock, shares outstanding (in shares) | shares	29,332,333
Class B common stock
Common stock, par value (in dollars per share) | $ / shares	$ 0.0001
Common stock, shares authorized (in shares) | shares	160,000,000
Common stock, shares issued (in shares) | shares	0
Common stock, shares outstanding (in shares) | shares	0
Class C common stock
Common stock, par value (in dollars per share) | $ / shares	$ 0.0001
Common stock, shares authorized (in shares) | shares	160,000,000
Common stock, shares issued (in shares) | shares	0
Common stock, shares outstanding (in shares) | shares	0
Class D common stock
Common stock, par value (in dollars per share) | $ / shares	$ 0.0001
Common stock, shares authorized (in shares) | shares	160,000,000
Common stock, shares issued (in shares) | shares	144,399,037
Common stock, shares outstanding (in shares) | shares	144,399,037

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Revenues:
Total revenues		$ 71,101	$ 66,550	$ 169,100	$ 168,814
Operating expenses:
Selling, general, and administrative		13,594	15,751	41,729	34,561
Depreciation, amortization, and accretion		3,739	3,380	10,934	10,101
Total expenses		69,228	68,485	184,872	169,428
Operating income (loss)		1,873	(1,935)	(15,772)	(614)
Other (expense) income:
Interest and financing expense, net		(2,885)	(790)	(4,482)	(7,212)
Loss on debt extinguishment		(953)	0	(2,848)	0
Change in fair value of derivative instruments, net		(138)	(1,908)	4,955	(1,580)
Other income		604	6,308	123,645	6,308
Income from equity method investments		1,726	3,694	1,433	3,658
Income before provision for income taxes		227	5,369	106,931	560
Provision for income taxes		0	0	0	0
Net income		227	5,369	106,931	560
Net (loss) income attributable to redeemable non-controlling interests		(2,104)	4,161	83,123	(2,584)
Net loss attributable to non-redeemable non-controlling interests		(51)	(325)	(531)	(824)
Dividends on Redeemable preferred non-controlling interests	[1]	2,782	2,658	8,394	5,093
Net (loss) income attributable to Class A common stockholders		$ (400)	$ (1,125)	$ 15,945	$ (1,125)
Weighted average shares outstanding of Class A common stock:
Basic (in shares)		26,978,969	25,671,390	27,110,953	25,671,390
Diluted (in shares)		26,978,969	25,823,772	27,683,855	25,823,772
Per share amounts:
Basic (in dollars per share)		$ (0.01)	$ (0.04)	$ 0.59	$ (0.04)
Diluted (in dollars per share)		$ (0.01)	$ (0.06)	$ 0.58	$ (0.06)
RNG Fuel
Revenues:
Total revenues		$ 20,088	$ 18,293	$ 37,468	$ 48,815
Operating expenses:
Cost of sales		8,896	10,872	24,303	27,043
Fuel Station Services
Revenues:
Total revenues		37,305	35,771	88,089	87,376
Operating expenses:
Cost of sales		31,887	30,837	79,655	74,130
Renewable Power
Revenues:
Total revenues		13,708	12,486	43,543	32,623
Operating expenses:
Cost of sales		$ 11,112	$ 7,645	$ 28,251	$ 23,593

[1] Paid-in-kind preferred dividend is allocated between redeemable non-controlling interests and Class A common stockholders based on their weighted average percentage of ownership. Please see Note.13 Redeemable non-controlling interests, redeemable preferred non-controlling interests and Stockholders' deficit for additional information.

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Total revenues	$ 71,101	$ 66,550	$ 169,100	$ 168,814
RNG Fuel
Total revenues	20,088	18,293	37,468	48,815
RNG Fuel | Related Party
Total revenues	18,782	15,481	32,909	36,326
Fuel Station Services
Total revenues	37,305	35,771	88,089	87,376
Fuel Station Services | Related Party
Total revenues	6,942	3,855	10,875	12,698
Renewable Power
Total revenues	13,708	12,486	43,543	32,623
Renewable Power | Related Party
Total revenues	$ 1,732	$ 927	$ 5,006	$ 3,196

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Statement of Comprehensive Income [Abstract]
Net income		$ 227	$ 5,369	$ 106,931	$ 560
Other comprehensive income:
Effective portion of the the cash flow hedge attributable to equity method investments		406	0	515	0
Reclassification adjustments included in earnings	[1]	0	0	(1,147)	0
Net unrealized gain (loss) on cash flow hedges		0	1,189	(141)	1,189
Total comprehensive income		633	6,558	106,158	1,749
Net income attributable to Redeemable non-controlling interests		230	6,509	90,166	2,199
Other comprehensive income (loss) attributable to Redeemable non-controlling interests		340	1,011	(649)	1,011
Comprehensive loss attributable to non-redeemable non-controlling interests		(51)	(325)	(531)	(824)
Dividends on Redeemable preferred non-controlling interests		448	310	1,351	310
Comprehensive (loss) income attributable to Class A common stockholders		$ (334)	$ (947)	$ 15,821	$ (947)

[1] Represents the reclassification of the gain on termination of interest rate swaps on May 30, 2023. See Note 9 Derivative Financial Instruments for additional information. Additionally, there is $334 reclassification into earnings from our equity method investments.

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) $ in Thousands	9 Months Ended
	Sep. 30, 2023 USD ($)
Statement of Comprehensive Income [Abstract]
Reclassification of adjustments into earnings	$ 334

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CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN REDEEMABLE NON-CONTROLLING INTEREST, REDEEMABLE PREFERRED NON-CONTROLLING INTEREST AND STOCKHOLDERS' (DEFICIT) EQUITY - USD ($) $ in Thousands		Total	Class A common stock	Class D common stock	Redeemable Preferred non-controlling interests	Redeemable non-controlling interests	Common stock Class A common stock	Common stock Class D common stock	Additional paid-in capital	Retained earnings (Accumulated deficit)	Other comprehensive income	Non-redeemable non-controlling interests	Class A common stock in treasury Class A common stock
Beginning balance at Dec. 31, 2021					$ 30,210	$ 63,545
Increase (Decrease) In Temporary Equity And Redeemable Noncontrolling Interest [Abstract]
Net loss						(4,225)
Contributions from non-redeemable non-controlling interest						(95)
Amortization on payment to acquire non-redeemable noncontrolling interest						(91)
Contributions from redeemable preferred non-controlling interests					25,000	(267)
Stock-based compensation						160
Paid-in-kind preferred dividend					717
Distribution of paid-in-kind preferred dividend						(717)
Ending balance at Mar. 31, 2022					55,927	58,310
Beginning balance (in shares) at Dec. 31, 2021							0	144,399,037
Beginning balance at Dec. 31, 2021		$ 1,202					$ 0	$ 14	$ 0	$ 0	$ 0	$ 1,188
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss		(242)										(242)
Proceeds from non-redeemable non-controlling interest		5,738										5,738
Ending balance (in shares) at Mar. 31, 2022							0	144,399,037
Ending balance at Mar. 31, 2022		6,698					$ 0	$ 14	0	0	0	6,684
Beginning balance at Dec. 31, 2021					30,210	63,545
Increase (Decrease) In Temporary Equity And Redeemable Noncontrolling Interest [Abstract]
Other comprehensive loss		1,011
Ending balance at Sep. 30, 2022					135,303	1,222,657
Beginning balance (in shares) at Dec. 31, 2021							0	144,399,037
Beginning balance at Dec. 31, 2021		1,202					$ 0	$ 14	0	0	0	1,188
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends on Redeemable preferred non-controlling interests		(310)
Ending balance (in shares) at Sep. 30, 2022							25,671,390,000	144,399,037
Ending balance at Sep. 30, 2022		(1,039,269)					$ 2	$ 14	0	(1,066,137)	178	26,674
Beginning balance at Mar. 31, 2022					55,927	58,310
Increase (Decrease) In Temporary Equity And Redeemable Noncontrolling Interest [Abstract]
Net loss						(85)
Contributions from non-redeemable non-controlling interest						47
Amortization on payment to acquire non-redeemable noncontrolling interest						(92)
Contributions from redeemable preferred non-controlling interests					75,000
Stock-based compensation						160
Paid-in-kind preferred dividend					1,718
Distribution of paid-in-kind preferred dividend						(1,718)
Ending balance at Jun. 30, 2022					132,645	56,622
Beginning balance (in shares) at Mar. 31, 2022							0	144,399,037
Beginning balance at Mar. 31, 2022		6,698					$ 0	$ 14	0	0	0	6,684
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss		(257)										(257)
Proceeds from non-redeemable non-controlling interest		11,211										11,211
Ending balance (in shares) at Jun. 30, 2022							0	144,399,037
Ending balance at Jun. 30, 2022		17,652					$ 0	$ 14	0	0	0	17,638
Increase (Decrease) In Temporary Equity And Redeemable Noncontrolling Interest [Abstract]
Net loss						6,509
Unrealized gain cash flow hedges						1,011
Other comprehensive loss		1,011
Stock-based compensation						140
Change in redemption value of Redeemable non-controlling interests						1,160,723
Paid-in-kind preferred dividend					2,658
Distribution of paid-in-kind preferred dividend						(2,348)
Ending balance at Sep. 30, 2022					135,303	1,222,657
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss		(1,140)								(815)		(325)
Unrealized gain cash flow hedges		178									178
Issuance of common stock from the reverse capitalization and PIPE investments, net of warrant liability, put option and earnout liabilities (in shares)							22,611,857,000
Issuance of common stock from the reverse capitalization and PIPE investments, net of warrant liability, put option and earnout liabilities		68,257					$ 2		68,255
Proceeds from non-redeemable non-controlling interest		6,203							(3,158)			9,361
Issuance of Class A common stock on warrant exchange (in shares)							3,059,533,000
Issuance of Class A common stock on warrant exchange		30,595							30,595
Stock-based compensation		19							19
Change in redemption value of Redeemable non-controlling interests		(1,160,723)							(95,711)	(1,065,012)
Paid-in-kind preferred dividend		(310)								(310)
Dividends on Redeemable preferred non-controlling interests		(310)
Ending balance (in shares) at Sep. 30, 2022							25,671,390,000	144,399,037
Ending balance at Sep. 30, 2022		(1,039,269)					$ 2	$ 14	0	(1,066,137)	178	26,674
Beginning balance at Dec. 31, 2022					138,142	1,013,833
Increase (Decrease) In Temporary Equity And Redeemable Noncontrolling Interest [Abstract]
Net loss						(5,915)
Other comprehensive loss						(299)
Stock-based compensation						814
Change in redemption value of Redeemable non-controlling interests						7,720
Paid-in-kind preferred dividend					2,763
Distribution of paid-in-kind preferred dividend						(2,318)
Ending balance at Mar. 31, 2023					140,905	1,013,835
Beginning balance (in shares) at Dec. 31, 2022			29,477,766	144,399,037			29,477,766	144,399,037
Beginning balance at Dec. 31, 2022		$ (774,156)					$ 3	$ 14	0	(800,813)	195	26,445	$ 0
Treasury stock, beginning balance (in shares) at Dec. 31, 2022		0											0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss		$ (1,431)								(1,134)		(297)
Other comprehensive loss		(58)									(58)
Proceeds from non-redeemable non-controlling interest		3,543							1,722			1,821
Issuance of Class A common stock on warrant exchange (in shares)							49,633
Issuance of Class A common stock on warrant exchange		338							338
Cancellation of fractional shares on warrant exchange (in shares)							(26)
Exercise of put option forward purchase contract - Meteora (in shares)													(1,635,783)
Exercise of put option forward purchase contract - Meteora		(11,614)											$ (11,614)
Forfeiture of Class A common stock (in shares)							(197,258)
Stock-based compensation		157							157
Change in redemption value of Redeemable non-controlling interests		(7,720)							(2,217)	(5,503)
Paid-in-kind preferred dividend		(445)								(445)
Ending balance (in shares) at Mar. 31, 2023							29,330,115	144,399,037
Ending balance at Mar. 31, 2023		(791,386)					$ 3	$ 14	0	(807,895)	137	27,969	$ (11,614)
Treasury stock, ending balance (in shares) at Mar. 31, 2023													(1,635,783)
Beginning balance at Dec. 31, 2022					138,142	1,013,833
Increase (Decrease) In Temporary Equity And Redeemable Noncontrolling Interest [Abstract]
Other comprehensive loss		(649)
Paid-in-kind preferred dividend					(16,536)
Ending balance at Sep. 30, 2023					130,000	1,158,937
Beginning balance (in shares) at Dec. 31, 2022			29,477,766	144,399,037			29,477,766	144,399,037
Beginning balance at Dec. 31, 2022		$ (774,156)					$ 3	$ 14	0	(800,813)	195	26,445	$ 0
Treasury stock, beginning balance (in shares) at Dec. 31, 2022		0											0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Contribution to equity method investments		$ 500
Dividends on Redeemable preferred non-controlling interests		(1,351)
Ending balance (in shares) at Sep. 30, 2023			29,332,333	144,399,037			29,332,333	144,399,037
Ending balance at Sep. 30, 2023		$ (852,060)					$ 3	$ 14	0	(841,417)	70	884	$ (11,614)
Treasury stock, ending balance (in shares) at Sep. 30, 2023		(1,635,783)											(1,635,783)
Beginning balance at Mar. 31, 2023					140,905	1,013,835
Increase (Decrease) In Temporary Equity And Redeemable Noncontrolling Interest [Abstract]
Net loss						95,851
Other comprehensive loss						(690)
Stock-based compensation						1,576
Change in redemption value of Redeemable non-controlling interests						(39,907)
Paid-in-kind preferred dividend					2,849
Distribution of paid-in-kind preferred dividend						(2,391)
Ending balance at Jun. 30, 2023					143,754	1,068,274
Beginning balance (in shares) at Mar. 31, 2023							29,330,115	144,399,037
Beginning balance at Mar. 31, 2023		$ (791,386)					$ 3	$ 14	0	(807,895)	137	27,969	$ (11,614)
Treasury stock, beginning balance (in shares) at Mar. 31, 2023													(1,635,783)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss		18,199								18,382		(183)
Other comprehensive loss		(133)									(133)
Proceeds from non-redeemable non-controlling interest		9,235							1,234			8,001
Deconsolidation of entities	[1]	(36,045)							(1,383)			(34,662)
Distributions to non-redeemable non-controlling interests		(222)										(222)
Stock-based compensation		301							301
Change in redemption value of Redeemable non-controlling interests		39,907							(152)	40,059
Paid-in-kind preferred dividend		(458)								(458)
Ending balance (in shares) at Jun. 30, 2023							29,330,115	144,399,037
Ending balance at Jun. 30, 2023		(760,602)					$ 3	$ 14	0	(749,912)	4	903	$ (11,614)
Treasury stock, ending balance (in shares) at Jun. 30, 2023													(1,635,783)
Increase (Decrease) In Temporary Equity And Redeemable Noncontrolling Interest [Abstract]
Net loss						230
Other comprehensive loss		340				340
Stock-based compensation						1,593
Change in redemption value of Redeemable non-controlling interests						90,834
Payment of paid-in-kind preferred dividends					(16,536)
Dividends on Redeemable preferred non-controlling interests					2,782
Distribution of Redeemable preferred non-controlling interests						(2,334)
Ending balance at Sep. 30, 2023					$ 130,000	$ 1,158,937
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss		(3)								48		(51)
Other comprehensive loss		66									66
Distributions to non-redeemable non-controlling interests		(25)							(57)			32
Issuance of Class A common stock on warrant exchange (in shares)							2,218
Issuance of Class A common stock on warrant exchange		(20)							(20)
Contribution to equity method investments		(500)							(500)
Stock-based compensation		306							306
Change in redemption value of Redeemable non-controlling interests		(90,834)							271	(91,105)
Dividends on Redeemable preferred non-controlling interests		(448)								(448)
Ending balance (in shares) at Sep. 30, 2023			29,332,333	144,399,037			29,332,333	144,399,037
Ending balance at Sep. 30, 2023		$ (852,060)					$ 3	$ 14	$ 0	$ (841,417)	$ 70	$ 884	$ (11,614)
Treasury stock, ending balance (in shares) at Sep. 30, 2023		(1,635,783)											(1,635,783)

[1] As of May 30, 2023, two of our RNG facilities, Emerald and Sapphire (defined below) were deconsolidated and accounted for under equity method as per ASC 323. Please see Note 4 Investment in Other entities and Note 12 Variable Interest Entities for additional information.

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CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN REDEEMABLE NON-CONTROLLING INTEREST, REDEEMABLE PREFERRED NON-CONTROLLING INTEREST AND STOCKHOLDERS' (DEFICIT) EQUITY (Parenthetical)	May 30, 2023 deconsolidated_entity
Number of deconsolidated entities	2
RNG Fuel
Number of deconsolidated entities	2

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Cash flows from operating activities:
Net income	$ 106,931	$ 560
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Income from equity method investments	(1,433)	(3,658)
Provision for bad debts	492	0
Amortization of operating right-of-use assets	460	518
Depreciation and amortization	10,627	9,866
Amortization of deferred financing costs	1,447	1,514
Loss on debt extinguishment	2,848	0
Loss on warrant exchange	338	0
Gain on deconsolidation of VIEs	(122,873)	0
Gain on extinguishment of contingent liability	0	(4,365)
Gain on repayment of Note receivable	0	(1,943)
Accretion expense related to asset retirement obligation	307	235
Stock-based compensation	4,747	479
Paid-in-kind interest income	(236)	(209)
Change in fair value of Convertible Note Payable	1,579	(151)
Unrealized gain on derivative financial instruments	(4,739)	1,677
Changes in operating assets and liabilities, net of effects of businesses acquired:
Accounts receivable	(409)	(11,269)
Accounts receivable, related party	12,421	0
Proceeds received on previously recorded paid-in-kind interest income	0	288
Fuel tax credits receivable	(242)	(1,049)
Capital spares	364	(308)
Parts inventory	(4,586)	(3,520)
Environmental credits held for sale	(2,665)	(838)
Prepaid expense and other current assets	2,229	(996)
Contract assets	(4,633)	(6,189)
Accounts payable	(931)	(6,734)
Accounts payable, related party	599	323
Fuel tax credits payable	400	690
Accrued payroll	(644)	(2,386)
Accrued expenses	4,195	8,561
Operating lease liabilities - current and non-current	(435)	(518)
Other current and non-current liabilities	(747)	453
Contract liabilities	(584)	(3,035)
Net cash provided by (used in) operating activities	4,827	(22,004)
Cash flows from investing activities:
Purchase of property, plant, and equipment	(92,250)	(85,234)
Proceeds (purchase ) of short term investments	46,948	(146,936)
Cash paid for Investment in other entities	(1,000)	0
Proceeds received from repayment Note Receivable	0	10,855
Deconsolidation of VIEs, net of cash	(11,947)	0
Distributions received from equity method investment	13,331	2,100
Net cash used in investing activities	(44,918)	(219,215)
Cash flows from financing activities:
Proceeds from Sunoma loan	0	4,593
Proceeds from OPAL Term Loan	174,117	27,500
Proceeds received from Business Combination	0	138,850
Cash paid for purchase of shares upon exercise of put option	(16,391)	0
Financing costs paid to other third parties	(11,062)	(8,462)
Repayment of Senior Secured Credit Facility	(22,750)	(3,674)
Repayment of OPAL Term Loan	(106,090)	(11,277)
Repayment of Municipality loan	(76)	(157)
Repayment of Convertible Note Payable	(30,107)	0
Proceeds from sale of non-redeemable non-controlling interest	12,753	23,152
Cash paid for taxes related to net share settlement of equity awards	(20)	0
Reimbursement of financing costs by joint venture partner	842	0
Payment of paid-in-kind preferred dividends	(16,536)	0
Distribution to non-redeemable non-controlling interest	(222)	0
Proceeds from sale of non-controlling interest, related party	0	100,000
Net cash (used in) provided by financing activities	(15,542)	270,525
Net (decrease) increase in cash, restricted cash, and cash equivalents	(55,633)	29,306
Cash, restricted cash, and cash equivalents, beginning of period	77,221	42,054
Cash, restricted cash, and cash equivalents, end of period	21,588	71,360
Supplemental disclosure of cash flow information
Interest paid, net of $4,627 and $0 capitalized, respectively	3,952	7,013
Noncash investing and financing activities:
Paid-in-kind dividend on redeemable preferred non-controlling interests	0	5,093
Accrual for purchase of Property, plant and equipment included in Accounts payable and Accrued capital expenses	7,355	9,284
Fair value of Class A common stock issued for redemption of Convertible Note Payable	0	30,595
Fair value of Derivative warrant liabilities assumed related to Business Combination	0	13,524
Fair value of Earnout liabilities related to Business Combination	0	45,900
Fair value of put option to a forward purchase contract related to Business Combination	0	4,600
Right-of-use assets for finance leases as of January 1, 2022 included in Property, plant and equipment, net	0	801
Lease liabilities for finance leases as of January 1, 2022 included in Accrued expenses and other current liabilities	0	316
Lease liabilities for finance leases as of January 1, 2022 included in Other long-term liabilities	0	485
Fair value of contingent consideration to redeem the non-controlling interest included in Other long-term liabilities	0	183
Accrual for deferred financing costs included in Accrued expenses and other current liabilities	$ 0	$ 282

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2023	Sep. 30, 2022
Statement of Cash Flows [Abstract]
Interest capitalized	$ 842	$ 4,627	$ 0

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Organization and Description of Business

9 Months Ended

Sep. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Description of Business

Organization and Description of Business

OPAL Fuels Inc. (including its subsidiaries, the "Company", “OPAL,” “we,” “us” or “our”) is a renewable energy company specializing in the capture and conversion of biogas for the (i) production of RNG for use as a vehicle fuel for heavy and medium-duty trucking fleets, (ii) generation of Renewable Power for sale to utilities, (iii) generation and sale of Environmental Attributes associated with RNG and Renewable Power, and (iv) sales of RNG as pipeline quality natural gas. OPAL also designs, develops, constructs, operates and services Fueling Stations for trucking fleets across the country that use natural gas to displace diesel as their transportation fuel. The biogas conversion projects ("Biogas Conversion Projects") currently use landfill gas and dairy manure as the source of the biogas. In addition, OPAL has 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.

The Company is organized into four operating segments based on the characteristics and the nature of products and services. The four operating segments are - RNG Fuel, Fuel Station Services, Renewable Power and Corporate. During the first quarter of 2023, the Company changed its internal reporting to its executive leadership team ("Chief Operating Decision Makers") to change the composition of revenues included in our reportable segments. Please see Note 11 Reportable Segments and Geographic Information for additional information.

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

COVID-19 Impact

In March 2020, the World Health Organization categorized the coronavirus disease 2019 ("COVID-19") as a pandemic and the President of the United States declared the COVID-19 outbreak as a national emergency. Management considered the impact of COVID-19 and determined that, because the Company was deemed an essential business by the U.S. government and did not perform layoffs of personnel or experience a decline in its customer base or business operations, there was no material adverse impact on the Company's statement of position and result of operations as of September 30, 2023, and for the three and nine months ended September 30, 2023.

The future impact of the COVID-19 pandemic on the Company's business will depend on a number of factors, including, but not limited to, the duration and severity of the pandemic and its impact on our customers, all of which are uncertain and cannot be predicted.

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Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Basis of Presentation and Principles of Consolidation

These unaudited condensed consolidated financial statements are prepared in accordance with generally accepted accounting principles in the United States ("U.S. GAAP") and include the accounts of the Company and all other entities in which the Company has a controlling financial interest: OPAL Renewable Power LLC (formerly Fortistar Methane 3 LLC (“FM3”) and Fortistar Methane 4 LLC), Beacon RNG LLC (“Beacon”) Sunoma Holdings, LLC (“Sunoma”), New River LLC (“New River”), Reynolds RNG LLC (“Reynolds”), Central Valley LLC (“Central Valley”), Prince William RNG LLC (“Prince William”), Cottonwood RNG LLC, Polk County RNG LLC (“Polk County”), OPAL Contracting LLC (formerly Fortistar Contracting LLC), OPAL RNG LLC (formerly Fortistar RNG LLC), and OPAL Fuel station services LLC (“Fuel Station Services”). The Company’s unaudited condensed consolidated financial statements include the assets and liabilities of these subsidiaries. All intercompany transactions and balances have been eliminated in consolidation. The non-controlling interest attributable to the Company's variable interest entities ("VIE") is presented as a separate component from the Stockholders' deficit in the condensed consolidated balance sheets. It is presented 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 the Stockholders' deficit.

The accompanying unaudited condensed consolidated financial statements reflect the activities of the Company, its subsidiaries, and its equity method investments for the three and nine months ended September 30, 2023 and 2022. Investments in unconsolidated entities in which the Company has influence over the operating or financial decisions are accounted for under the equity method. On May 30, 2023, the Company together with a third-party environmental solutions company formed Paragon LLC ("Paragon"), a new joint venture holding company. The Company owns 50% of the ownership interest in Paragon. Concurrent to the formation of Paragon, the Company contributed its 50% ownership interests in Emerald and Sapphire to Paragon. Upon the execution of the above transaction, the Company reassessed its equity interests in Emerald RNG LLC ("Emerald") and Sapphire RNG LLC ("Sapphire") under ASC 810, Consolidation and determined that the Company did not have a controlling financial interest in Paragon under ASC 810 because the governance of Paragon is driven by a board jointly controlled equally by the joint venture partner and the Company and there are substantive participating rights held by the joint venture partner in the significant activities of Paragon. As a result of the reassessment, the Company deconsolidated these two entities effective May 30, 2023. Prior to May 30, 2023, the Company consolidated these two entities in accordance with the variable interest entity model guidance under ASC 810, Consolidation.

On September 14, 2023, OPAL Land2Gas LLC (“OPAL L2G”), a wholly-owned indirect subsidiary of OPAL Fuels Inc. (the “Company”), entered into a Limited Liability Company Agreement (for purposes of this paragraph, the “Agreement”) with SJI Landfill RNG LLC (“SJI LRNG”), a wholly-owned indirect subsidiary of South Jersey Industries (“SJI”), establishing the terms and conditions of governance and operation of Land2Gas LLC (the “ SJI Joint Venture”). The purpose of the Joint Venture, which is owned 50/50 by OPAL L2G and SJI LRNG, is to develop, construct, own and operate facilities (“Facilities”) to produce RNG using biogas generated by certain landfills. The Agreement governs the terms and conditions of capital contributions to be made by the SJI Joint Venture members to fund the development, construction and operations of the Facilities. The Agreement requires members of the SJI Joint Venture to contribute their respective share (50% each) of such capital requirements. The Agreement initially contemplates two RNG projects (RNG Atlantic and RNG Burlington) in New Jersey with each RNG project represented as a separate series of membership interests, also owned 50-50 by the members. Further, the Agreement provides for the SJI Joint Venture to enter into a Management Services Agreement (“MSA”), Operations and Maintenance Agreement (“O&M Agreement”), and dispensing agreement with certain wholly-owned, indirect subsidiaries of the Company. The MSA establishes the terms and conditions for the day-to-day administration of the projects, including responsibility for managing the development and overseeing the construction of the Facilities. The O&M Agreement establishes the terms and conditions for operating and maintaining the Facilities once construction is completed. The Dispensing Agreement provides for the acquisition, marketing and sale of the Environmental Attributes associated with RNG produced by the Facilities.

Upon the execution of the above transaction, the Company reassessed its equity interests in the SJI Joint Venture under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in SJI Joint Venture under ASC 810 because the governance of the joint venture is driven by a board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of SJI Joint Venture. As of September 30, 2023, there have been no material contributions made by the Company in the SJI Joint Venture.

As of September 30, 2023, the Company accounted for its ownership interests in Pine Bend RNG LLC ("Pine Bend"), Noble Road RNG LLC ("Noble Road"), Emerald, Sapphire, Paragon, SJI Joint Venture (RNG Atlantic and RNG Burlington) and GREP BTB Holdings LLC ("GREP") under the equity method.

As of December 31, 2022, the Company accounted for its ownership interests in Pine Bend, Noble Road and GREP under the equity method. Please see Note 3. Investment in Other Entities, for additional information.

The accompanying unaudited condensed financial statements have been prepared in accordance with the instructions to Form 10-Q and Article 10 of Regulation S-X of the Securities and Exchange Commission ("SEC"). Certain information or footnote disclosures normally included in financial statements prepared in accordance with U.S. GAAP have been condensed or omitted, pursuant to the rules and regulations of the SEC for interim financial reporting. Accordingly, it does not include all the information and footnotes necessary for a complete presentation of financial position, results of operations, or cash flows. The information herein should be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company's Annual Report. In the opinion of management, the accompanying unaudited condensed financial statements include all adjustments, consisting of a normal recurring nature, which are necessary for a fair statement of the financial position, operating results, and cash flows for the periods presented.

Use of Estimates

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

The significant estimates and assumptions of the Company include the residual value of the useful lives of our property, plant and equipment, the fair value of stock-based compensation, asset retirement obligations, the estimated losses on our trade receivables, percentage completion for revenue recognition, incremental borrowing rate for calculating the right-of-use assets and lease liabilities, the impairment assessment of goodwill, the fair value of deconsolidated VIEs 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.

Accounting Pronouncements Adopted

In June 2016, the Financial Standards Accounting Board ("FASB") issued ASU 2016-13, Financial Instruments — Credit Losses ("ASC 326"), with the objective of providing information about the credit risk inherent in an entity’s financial statements as well as to explain management’s estimate of expected credit losses and the changes in the allowance for such losses. The accounting standard amends the current financial instrument impairment model by requiring entities to use a forward-looking approach based on expected losses to estimate credit losses on certain types of financial instruments, including trade receivables. Under the new guidance, an entity recognizes as an allowance, its estimate of lifetime expected credit losses, which will result in more timely recognition of such losses. The Company adopted the accounting standard using the prospective transition approach as of January 1, 2023. The cumulative effect upon adoption was not material to our condensed consolidated financial statements.

The adoption of ASC 326 primarily impacted our trade receivables and the Note receivable - variable fee component recorded on our condensed consolidated balance sheet as of September 30, 2023. Upon adoption of ASC 326, the Company assessed collectability by reviewing accounts receivable on a collective basis where similar characteristics exist and on an individual basis when we identify specific customers with known disputes or collectability issues. In determining the amount of the allowance for credit losses, the Company considered historical collectability based on past due status and made judgments about the creditworthiness of customers based on ongoing credit evaluations. The Company also considered customer-specific information, current market conditions and reasonable and supportable forecasts of future economic conditions to inform adjustments to historical loss data. The carrying value of the Note receivable - variable fee component on the condensed consolidated balance sheet as of September 30, 2023 is based on a discounted expected cash flows model which is adjusted on a quarterly basis. Therefore, the Company determined that the credit risk component is included in the carrying value at each reporting period. The adoption of ASC 326 did not have any material impact on our condensed consolidated financial statements.

Accounting Pronouncements Not Yet Adopted

In March 2023, the FASB issued Accounting Standards Update No. 2023-01, Leases (Topic 842) (the "Update"). The Update requires the entities to classify and account for a leasing arrangement between entities under common control on the same basis as an arrangement with an unrelated party. The Update also requires that leasehold improvements associated with common control leases be amortized by the lessee over the useful life of the leasehold improvements to the common control group (regardless of the lease term) as long as the lessee controls the use of the underlying asset and accounts for the underlying asset as a transfer between entities under common control through an adjustment to equity if and when the lessee no longer controls the use of the underlying asset. The amendments in this Update are effective for fiscal years beginning after December 15, 2023 including interim fiscal periods within those fiscal years. The Company is currently evaluating the impact of the adoption of this Update on its condensed consolidated financial statements.

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. The Company is currently evaluating the impact of the adoption of ASU 2023-05 on its condensed consolidated financial statements.

Emerging Growth Company Status

The Company is an emerging growth company as defined in the JOBS Act. The JOBS Act provides emerging growth companies with certain exemptions from public company reporting requirements for up to five fiscal years while a company remains an emerging growth company. As part of these exemptions, the Company is only required to provide two fiscal years of audited financial statements instead of three, is subject to reduced disclosure obligations and is not required to comply with auditor attestation requirements from Section 404(b) of the Sarbanes-Oxley Act regarding our internal control over financial reporting. Additionally, the JOBS Act allows the Company to delay adoption of new or revised financial accounting standards until private companies are required to comply with new or revised financial accounting standards.

Cash, Cash Equivalents, and Restricted Cash

Cash, cash equivalents, and restricted cash consisted of the following as of September 30, 2023 and December 31, 2022:

	September 30, 2023		December 31, 2022
Current assets:
Cash and cash equivalents	$	15,000	$	40,394
Restricted cash - current (1)	1,232		32,402
Long-term assets:
Restricted cash held as collateral (2)	5,356		4,425
Total cash, cash equivalents, and restricted cash	$	21,588	$	77,221

(1) Restricted cash - current as of September 30, 2023 primarily relates to interest reserve on the Sunoma Loan. Restricted cash - current as of December 31, 2022 primarily consists of (i) $16,849 held in escrow to secure the Company's purchase obligations under the forward purchase agreement with Meteora Capital Partners ("Meteora"); (ii) $5,845 equity contribution to a joint venture in connection with the closing of OPAL Term Loan II (iii) $1,127 related to interest reserve on the Sunoma Loan and (iv) $8,581 held in a restricted account for funding one of our RNG projects. The decrease in Restricted cash - current relates to the completed performance of the forward purchase agreement with Meteora and funds spent on construction of our RNG facilities.

(2) Restricted cash held as collateral represents the collateral requirements on our debt facilities.

Short term investments

The Company considers highly liquid investments such as time deposits and certificates of deposit with an original maturity greater than three months at the time of purchase to be short term investments. The short term investments of $18,028 and $64,976 as of September 30, 2023 and December 31, 2022, respectively, consist of commercial paper invested in money market accounts with maturities ranging between 1 and 12 months as of the reporting date. The amounts in these accounts are liquid and available for general use.

Our short term investments are generally invested in commercial paper issued by highly credit worthy counter parties and government-backed treasury bills. Investments are generally not FDIC insured and we take counterparty risk on these investments.

Earnout liabilities

In connection with the business combination ("Business Combination") completed in July 2022 and pursuant to a sponsor letter agreement, ArcLight CTC Holdings II, L.P. (the "Sponsor") 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. OPAL Fuels equity holders are eligible to receive an aggregate of 10,000,000 shares of Class B and Class D common stock upon the Company achieving each earn-out event during the earn-out period. The earnout awards (the "Earnout Awards") were recognized at fair value on the closing date and classified as a liability

which is remeasured at each balance sheet date and any change in fair value is recognized in the Company's condensed consolidated statement of operations as part of change in fair value of derivative instruments, net. For the three and nine months ended September 30, 2023, the Company recorded a loss of $(138) and a gain of $4,499, respectively, in its condensed consolidated statement of operations. For the three and nine months ended September 30, 2022, the Company recorded a gain of $6,400 in its condensed consolidated statement of operations. As of September 30, 2023 and December 31, 2022, the Company recorded $4,291 and $8,790, respectively, on its condensed consolidated balance sheets.

Put Option On Forward Purchase Agreement

Prior to the closing of the Business Combination, the Company entered into a Forward Purchase Agreement with Meteora pursuant to which Meteora agreed to purchase 2,000,000 shares of Class A common stock from shareholders who had previously tendered such shares for redemption but agreed to reverse their redemption and sell such shares to Meteora at the redemption price. The Company placed $20,040 in escrow at the closing of the Business Combination to secure its purchase obligation to repurchase these 2,000,000 shares at Meteora’s option for a price of $10.02 per share on the date that is six months after closing of the Business Combination. The put option written to Meteora on 2,000,000 shares of Class A common stock is recorded as a liability under Topic 480 Distinguishing Liabilities from Equity with the change in the fair market value recognized in the statement of operations as part of change in fair value of derivative instruments, net.

On January 23, 2023, pursuant to the terms of the Forward Purchase Agreement, Meteora exercised its option to sell back 1,635,783 shares to the Company. $16,391 of the funds held in escrow which were previously recorded as part of Restricted Cash - current on the Company's consolidated balance sheet as of December 31, 2022 were released to Meteora (excluding accrued interest). In connection with the above, the Sponsor forfeited 197,258 shares of Class A common stock on January 26, 2023 pursuant to the terms of that certain Letter Agreement dated July 21, 2022. The Company treated the repurchased shares as treasury shares and recorded $11,614 representing the fair value of those shares at the closing share price of $7.01 as an adjustment to Stockholders' deficit. Additionally, the Company recorded $4,777 as an offset to the Derivative financial liability - current in its condensed consolidated balance sheet as of September 30, 2023.

Redeemable non-controlling interests

Redeemable non-controlling interests represent the portion of OPAL Fuels that the Company controls and consolidates but does not own. The Redeemable non-controlling interest was created as a result of the Business Combination and represents 144,399,037 Class D 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 statement of operations.

At each balance sheet date, the mezzanine equity classified as Redeemable non-controlling interests is adjusted up to its maximum redemption value if necessary, with an offset in Stockholders' equity. As of September 30, 2023, the maximum redemption value is $1,158,937.

Net Income Per Share

The Company's basic earnings per share of Class A common stock is computed based on the average number of outstanding shares of Class A common stock for the period.

The Company's diluted earnings per share includes effects of the Company's outstanding equity awards under the 2022 Plan (as defined elsewhere in these financial statements), Redeemable non-controlling interests (OPAL Fuels Class B units), redeemable preferred non-controlling interests, Sponsor Earnout Awards and OPAL Earnout Awards.

Accounts Receivable, Net

The Company's allowance for doubtful accounts was $0 and $0 at September 30, 2023 and December 31, 2022, respectively.

Asset Retirement Obligation

The Company accounts for asset retirement obligations in accordance with FASB ASC 410, Asset Retirement and Environmental Obligations, which requires entities to record 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 fair value of the estimated asset retirement obligations is recorded as a long-term liability, with a corresponding increase in the carrying amount of the related asset. The discounted asset retirement costs capitalized amounts are accreted over the life of the sublease or site lease agreement. Asset retirement obligations are deemed Level 3 fair value measurements as the inputs used to measure the fair value are unobservable. The Company estimates the fair value of asset retirement obligations by calculating the estimated present value of the cost to retire the asset. This estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental, and political environments. In addition, the Company determines the Level 3 fair value measurements based on historical information and current market conditions.

As of September 30, 2023 and December 31, 2022, the Company estimated the value of its total asset retirement obligations to be $6,563 and $6,256, respectively.

The changes in the asset retirement obligations were as follows as of September 30, 2023:

	September 30, 2023
Balance, December 31, 2022 - Current and non-current	$	6,256
Accretion expense	307
Total asset retirement obligation	6,563
Less: current portion	(1,296)
Total asset retirement obligation, net of current portion	$	5,267

Revenue Recognition

The Company’s revenue arrangements generally consist of a single performance obligation to transfer goods or services. Revenue from the sale of RNG, CNG and electricity is recognized by applying the “right to invoice” practical expedient within the accounting guidance for Revenue from Contracts with Customers that allows for the recognition of revenue from performance obligations in the amount of consideration to which there is a right to invoice the customer and when the amount for which there is a right to invoice corresponds directly to the value transferred to the customer. For some public CNG Fueling Stations where there is no contract with the customer, the Company recognizes revenue at the point in time that the customer takes control of the fuel.

The Company also performs maintenance services throughout the country. Maintenance consists of monitoring equipment and replacing parts as necessary to ensure optimum performance. Revenue from service agreements is recognized over time as services are provided. Capacity payments fluctuate based on peak times of the year and revenues from capacity payments are recognized monthly as earned.

The Company has agreements with two natural gas producers ("Producers") to transport Producers' natural gas using the Company's RNG gathering system. The performance obligation is the delivery of Producers' natural gas to an agreed delivery point on an interstate gas pipeline. The quantity of natural gas transported for the Producers is measured at a certain specified meter. The price is fixed at contracted rates and the Producers pay approximately 30 days after month-end. As such, transportation sales are recognized over time, using the output method to measure progress.

The Company provides credit monetization services to customers that own renewable gas generation facilities. The Company recognizes revenue from these services as the credits are minted on behalf of the customer. The Company receives non-cash consideration in the form of Renewable Identification Numbers ("RINs") or LCFSs for providing these services and recognizes the RINs or LCFSs received as a current asset based on their estimated fair value at contract inception. When the Company receives RINs or LCFSs as payment for providing credit monetization services, it records the non-cash consideration in environmental credits held for sale within the unaudited condensed consolidated balance sheet based on the fair value of RINs or LCFSs at contract commencement.

On November 29, 2021, the Company entered into a purchase and sale agreement with NextEra, a related party for the Environmental Attributes generated by the RNG Fuels business. Under this agreement, the Company plans to sell a minimum of 90% of the Environmental Attributes generated and will receive net proceeds based on the agreed upon price

less a specified discount. A specified volume of Environmental Attributes sold per quarter will incur a fee per Environmental Attribute in addition to the specified discount. The agreement was effective beginning January 1, 2022. For the three months ended September 30, 2023 and 2022, the Company earned net revenues after discount and fees of $25,724 and $19,336, respectively. These amounts were recorded as part of Revenues - RNG fuel and Fuel Station Services. For the nine months ended September 30, 2023 and 2022, the Company earned net revenues after discount and fees of $43,784 and $49,024, respectively.

During third and fourth quarter of 2022, two of the wholly-owned subsidiaries from our Renewable Power portfolio entered into a purchase and sale agreement with an environmental attribute marketing firm to sell environmental attributes associated with renewable bio methane ("ISCC Carbon Credits") and purchase brown gas back at contracted fixed prices per million British thermal units ("MMbtu"). One of these contracts has a term of 3 years from the date of certification of the facility with an auto-renewal option. The other contract was terminated in August 2023. During the third quarter of 2023, two additional Renewable Power facilities entered into purchase and sale agreements with 3 year terms and similar terms and conditions as the previous contracts. These two facilities are expected to receive certification in the fourth quarter of 2023. These two facilities are expected to receive certification in the fourth quarter of 2023. For the three and nine months ended September 30, 2023, the Company earned net revenues of $3,732 and $13,425, respectively under this contract which were recorded as part of Revenues - Renewable Power in the unaudited condensed consolidated statement of operations. For the three and nine months ended September 30, 2022, the Company earned net revenues of $842 and recorded as part of Revenues - Renewable Power in the condensed consolidated statement of operations.

Sales of Environmental Attributes such as RINs, renewable energy credits ("RECs"), and LCFS are generally recorded as revenue when the certificates related to them are delivered to a buyer. However, the Company may recognize revenue from the sale of such Environmental Attributes at the time of the related renewable power sales when the contract provides that title to the Environmental Attributes transfers at the time of production, the Company's price to the buyer is fixed, and collection of the sales proceeds is certain.

Management operating fees are earned for the operation, maintenance, and repair of the gas collection system of a landfill site. Revenue is calculated on the volume of per MMBtu of LFG collected and the megawatt hours ("MWhs") produced at that site. This revenue is recognized when LFG is collected and renewable power is delivered.

The Company has various fixed price contracts for the construction of Fueling Stations for customers. Revenues from these contracts, including change orders, are recognized over time, with progress measured by the percentage of costs incurred to date compared to estimated total costs for each contract. This method is used as management considers costs incurred to be the best available measure of progress on these contracts. Costs capitalized to fulfill certain contracts were not material in any of the periods presented.

The Company owns Fueling Stations for use by customers under fuel sale agreements. The Company bills these customers at an agreed upon price for each gallon sold and recognizes revenue based on the amounts invoiced in accordance with the "right to invoice" practical expedient. For some public stations where there is no contract with the customer, the Company recognizes revenue at the point-in-time that the customer takes control of the fuel.

The Company from time-to-time enters into fuel purchase agreements with customers whereby 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. In accordance with the standards of ASC 840, Leases, the Company has concluded that these agreements meet the criteria for a lease and are classified as operating leases. Typically, these agreements do not require any minimum consumption amounts and, therefore, no minimum payments. Upon adoption of ASC 842, the Company adopted the practical expedient not to reassess the classification. For additional information on lease revenues earned, please see Note 8. Leases.

Disaggregation of Revenue

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Electricity sales	$	8,929	$	9,666	$	26,925	$	27,205
Third party construction	15,182		18,661		37,429		41,476
Fuel Station Service	4,824		3,480		13,728		11,910
Brown gas sales	1,917		12,430		17,268		23,398
Environmental attributes	38,480		19,648		68,848		58,444
Parts sales	629		1,355		1,965		2,332
Operating agreements	—		—		—		893
Other	—		70		—		236
Total revenue from contracts with customers	69,961		65,310		166,163		165,894
Lease revenue	1,140		1,240		2,937		2,920
Total revenue	$	71,101	$	66,550	$	169,100	$	168,814

For the three months ended September 30, 2023 and 2022, 21.4% and 28.0%, respectively of revenue was recognized over time, and the remainder was for products and services transferred at a point in time. For the nine months ended September 30, 2023 and 2022, 22.1% and 24.6%, respectively of revenue was recognized over time, and the remainder was for products and services transferred at a point in time.

Other income

The following table shows the items recorded as Other income:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Loss on warrant exchange	$	—	$	—	$	(338)	$	—
Gain on deconsolidation of VIEs (1)	—		—		122,873		—
Gain on extinguishment of contingent liability	—		4,365		—		4,365
Gain on repayment of Note Receivable	—		1,943		—		1,943
Gain on transfer of non-financial asset in exchange for services received (2)	604		—		1,110		—
Other income	$	604	$	6,308	$	123,645	$	6,308

(1) Represents non-cash gain on deconsolidation of Emerald and Sapphire on May 30, 2023.

(2) Represents the fair value of RINs transferred as consideration for services received.

Contract Balances

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

	September 30, 2023		December 31, 2022
Accounts receivable, net	$	31,000	$	31,083
Contract assets:
Cost and estimated earnings in excess of billings	$	10,975	$	7,027
Accounts receivable retainage, net	3,429		2,744
Contract assets total	$	14,404	$	9,771
Contract liabilities:
Billings in excess of costs and estimated earnings	$	7,429	$	8,013
Contract liabilities total	$	7,429	$	8,013

During the nine months ended September 30, 2023, the Company recognized revenue of $8,013 that was included in "Contract liabilities" at December 31, 2022. During the nine months ended September 30, 2022, the Company recognized revenue of $9,785 that was included in "Contract liabilities" at December 31, 2021.

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 September 30, 2023, the Company had a Backlog of $46,549 which is anticipated to be recognized as revenue in the next 12 months.

Income Taxes

As a result of the Business Combination, the Company is the sole managing member of OPAL Fuels. OPAL Fuels is a limited liability company that is treated as a partnership for U.S. federal income tax purposes and for most applicable state and local income taxes. Any taxable income or loss generated by OPAL Fuels is passed through to and included in the taxable income or loss of its members, including the Company, on a pro-rata basis, subject to applicable tax regulations.

The Company accounts for income taxes in accordance with ASC Topic 740, Accounting for Income Taxes (“ASC Topic 740”), which requires the recognition of tax benefits or expenses on temporary differences between the financial reporting and tax bases of its assets and liabilities by applying the enacted tax rates in effect for the year in which the differences are expected to reverse. Such net tax effects on temporary differences are reflected on the Company’s unaudited condensed consolidated balance sheets as deferred tax assets and liabilities. Deferred tax assets are reduced by a valuation allowance when the Company believes that it is more-likely-than-not that some portion or all of the deferred tax assets will not be realized. The Company calculates the interim tax provision in accordance with the provisions of ASC Subtopic 740-270, Income Taxes; Interim Reporting. For interim periods, the Company estimates the annual effective income tax rate and applies the estimated rate to the year-to-date income or loss before income taxes.

Significant Customers, Vendors and Concentration of Credit Risk

For the three and nine months ended September 30, 2023, two customers accounted for 49% and 41%, respectively of the Company's revenue. For the three and nine months ended September 30, 2022, two customers accounted for 49% and 45%, respectively of the Company's revenue. At September 30, 2023, one customers accounted for 22% of accounts receivable. At December 31, 2022, two customers accounted for 44% of accounts receivable.

Financial instruments that potentially subject the Company to concentrations of credit risk consist principally of cash and cash equivalents, and trade receivables. The Company places its cash in high credit quality financial institutions located in the United States of America. The Company performs ongoing credit evaluations of its customers.

As of September 30, 2023, two vendors accounted for 39% of the accounts payable. As of December 31, 2022, one vendor accounted for 19% of the accounts payable.

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Investments in Other Entities

9 Months Ended

Sep. 30, 2023

Equity Method Investments and Joint Ventures [Abstract]

Investments in Other Entities

Investment in Other Entities

The Company uses the equity method to account for investments in affiliates that it does not control, but in which it has the ability to exercise significant influence over operating and financial policies. The Company's investments in these nonconsolidated affiliates are reflected in the Company's condensed consolidated balance sheets under the equity method, and the Company's proportionate net (loss) income, if any, is included in the Company's unaudited condensed consolidated statements of operations as (loss) income from equity method investments.

Formation Of A New Joint Venture

On September 14, 2023, OPAL L2G, a wholly-owned indirect subsidiary of the Company, entered into the Agreement with SJI LRNG, a wholly-owned indirect subsidiary of SJI, establishing the terms and conditions of governance and operation of the SJI Joint Venture. The purpose of the SJI Joint Venture, which is owned 50/50 by OPAL L2G and SJI LRNG, is to develop, construct, own and operate Facilities to produce RNG using biogas generated by certain landfills. The Agreement governs the terms and conditions of capital contributions to be made by the SJI Joint Venture members to fund the development, construction and operations of the Facilities. The Agreement requires members of the SJI Joint Venture to contribute their respective share (50% each) of such capital requirements. The Agreement initially contemplates two RNG projects (RNG Atlantic and RNG Burlington) in New Jersey with each RNG project represented as a separate series of membership interests, also owned 50-50 by the members. Further, the Agreement provides for the SJI Joint Venture to enter into a MSA, O&M Agreement, and dispensing agreement with certain wholly-owned, indirect subsidiaries of the Company. The MSA establishes the terms and conditions for the day-to-day administration of the projects, including responsibility for managing the development and overseeing the construction of the Facilities. The O&M Agreement establishes the terms and conditions for operating and maintaining the Facilities once construction is completed. The Dispensing Agreement provides for the acquisition, marketing and sale of the Environmental Attributes associated with RNG produced by the Facilities.

Upon the execution of the above transaction, the Company reassessed its equity interests in the SJI Joint Venture under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in SJI Joint Venture under ASC 810 because the governance of the joint venture is driven by a board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of SJI Joint Venture. As of September 30, 2023, there have been no material contribution made by the Company in the SJI Joint Venture.

Deconsolidation of Emerald and Sapphire

On May 30, 2023, the Company together with a third-party environmental solutions company formed Paragon. The Company owns 50% of the ownership interest in Paragon. Concurrent to the formation of Paragon, the Company contributed its 50% ownership interests in Emerald and Sapphire to Paragon.

On May 30, 2023, OPAL Fuels Intermediate Holdco 2 LLC (“OPAL Intermediate Holdco 2”), a wholly-owned indirect subsidiary of the Company, assigned to Paragon its rights and obligations under its existing senior secured credit facility, OPAL Term Loan II.

Upon the execution of the above two transactions, the Company reassessed its equity interests in Emerald and Sapphire under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in Paragon under ASC 810 because the governance of the Paragon is driven by a board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of Paragon.

Based on the above analysis, the Company determined that it should account for its ownership interests in Paragon under the equity method of accounting pursuant to ASC 323, Investments Equity Method and Joint Ventures, prospectively, as the Company has the ability to exercise significant influence, but not control over the joint venture company.

Prior to May 30, 2023, the Company consolidated these two entities in accordance with the variable interest entity model guidance under ASC 810, Consolidation. Additionally, the Company deconsolidated $2,765 capitalized interest on these two projects. Upon deconsolidation, the Company remeasured the fair value of the retained investment and recognized a gain of $122,873 in the condensed consolidated statement of operations for the nine months ended September 30, 2023 and a corresponding increase in its basis in Investment in Other Entities on its condensed consolidated balance sheet as of September 30, 2023. The Company determined that the gain on deconsolidation is attributable to the

construction in progress and, therefore, will be amortized over the useful life of the asset which begins on the date the asset is placed in service. The fair value of the retained investment was measured based on a discounted cash flows model in which the future net cash flows from the two RNG facilities were discounted to their present value using a discount factor of 14%.

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

	Pine Bend			Paragon			Noble Road			GREP			Total
Percentage of ownership	50		%	50		%	50		%	20		%
Balance at December 31, 2022	$	22,518		$	—		$	25,165		$	4,082		$	51,765
Deconsolidation of Emerald and Sapphire	—			34,662			—			—			34,662
Deconsolidation of deferred financing costs and capitalized interest	—			1,383			—			—			1,383
Net income from equity method investment (1)	1,884			(1,190)			3,190			(810)			3,074
Reclassification of adjustments into earnings	—			—			—			(334)			(334)
Contribution by the Company (2)	—			500			—			—			500
Distributions from return of investment in equity method investment	(3,525)			(3,585)			(5,700)			(521)			(13,331)
Accumulated other comprehensive income	—			515			—			—			515
Gain on deconsolidation of Emerald and Sapphire (3)	—			122,873			—			—			122,873
Amortization of basis difference (1)	(218)			(388)			(1,035)			—			(1,641)
Balance at September 30, 2023	$	20,659		$	154,770		$	21,620		$	2,417		$	199,466

(1) Reflected in Income from equity method investments in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022.

(2) Represents 50% of the $1,000 contributed by the Company in the third quarter of 2023.

(3) Recorded as part of Other income in our condensed consolidated statement of operations for the three and nine months ended September 30, 2023.

Note receivable

In August 2021, the Company acquired 100% ownership interest in Reynolds which held a Note receivable of $10,450 to Biotown. The Note receivable had a maturity date of July 15, 2027 and carried an interest rate of 12.5% of which 8% is payable in cash on a quarterly basis from the inception of the loan and 4.5% payment-in-kind interest adding to the outstanding debt balance until the facility becomes operational.

On July 15, 2022, Biotown repaid the total amount outstanding under the Note receivable including paid-in-kind interest and prepayment penalty.

The Note receivable also entitles Reynolds to receive 4.25% of any revenue-based distributions made up to a maximum of $4,500 over the term of the debt. The Company recorded the fair value of the Note receivable — variable fee component of $1,538 as an allocation of the initial investment balance of $10,450 and recorded payment-in-kind interest income of $81 and $236 as a reduction in the interest and financing expense, net in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023, respectively. The Company recorded $73 and $209 as a reduction to interest and financing expense, net in its condensed consolidated statement of operations for the three and nine months ended September 30, 2022.

The Note receivable - variable fee component of $2,178 and $1,942 is recorded as a long-term asset on its condensed consolidated balance sheets as of September 30, 2023 and December 31, 2022, respectively.

The following table summarizes the net income from equity method investments:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Revenue (1)	$	9,463	$	42,158	$	23,927	$	47,247
Gross profit	(11,268)		33,053		(1,392)		34,665
Net income	4,533		31,356		1,634		29,615
Net income from equity method investments (2)	$	1,726	$	3,694	$	1,433	$	3,658

(1) Revenues include a realized gain of $32,796 from commodity swap contracts on our equity method investment, GREP for the three and nine months ended September 30, 2022.

(2) Net income from equity method investments represents our portion of the net income from equity method investments including amortization of any basis differences.

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Property, Plant, and Equipment, Net

9 Months Ended

Sep. 30, 2023

Property, Plant and Equipment [Abstract]

Property, Plant, and Equipment, Net

Property, Plant, and Equipment, Net

Property, plant, and equipment, net, consisted of the following as of September 30, 2023 and December 31, 2022:

	September 30, 2023		December 31, 2022
Plant and equipment	$	203,473	$	201,655
CNG/RNG fueling stations	46,892		34,567
Construction in progress (1)	150,649		152,105
Buildings	2,585		2,585
Land	1,303		1,303
Service equipment	2,207		1,888
Leasehold improvements	815		815
Vehicles	231		313
Office furniture and equipment	307		307
Computer software	277		277
Vehicles - finance leases	1,708		1,236
Other	571		487
	411,018		397,538
Less: accumulated depreciation	(107,328)		(100,215)
Property, plant, and equipment, net	$	303,690	$	297,323

(1) Includes $4,101 and $3,081 of capitalized interest on our OPAL Term Loan facility as of September 30, 2023 and December 31, 2022.

As of September 30, 2023, the construction in progress balance consists of our investment in the construction of RNG generation facilities including, but not limited to Prince William, Central Valley RNG projects and RNG dispensing facilities. The majority of these facilities, for which costs are in construction in progress as of September 30, 2023, are expected to be operational during the fourth quarter of 2023 and early 2024. As of December 31, 2022, the construction in progress balance consists of our investment in the construction of RNG generation facilities such as Emerald, Sapphire, Prince William, Central Valley and other RNG dispensing facilities.

Depreciation expense on property, plant, and equipment for the three months ended September 30, 2023 and 2022 was $3,485 and $2,992, respectively. The depreciation expense for the nine months ended September 30, 2023 and September 30, 2022 was $10,162 and $9,271, respectively.

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Intangible Assets, Net

9 Months Ended

Sep. 30, 2023

Goodwill and Intangible Assets Disclosure [Abstract]

Intangible Assets, Net

Intangible Assets, NetIntangible assets, net, consisted of the following at September 30, 2023 and December 31, 2022:

	September 30, 2023
	Cost		Accumulated Amortization		Intangible Assets, Net		Weighted Average Amortization Period (Years)
Power purchase agreements	$	8,999	$	(7,889)	$	1,110	18.1
Transmission/distribution interconnection	1,600		(1,019)		581		15.1
Intellectual property	43		(34)		9		5.0
Total intangible assets	$	10,642	$	(8,942)	$	1,700

	December 31, 2022
	Cost		Accumulated Amortization		Intangible Assets, Net		Weighted Average Amortization Period (years)
Power purchase agreements	$	8,999	$	(7,488)	$	1,511	18.1
Transmission/distribution interconnection	1,600		(971)		629		15.1
CNG sales contract	807		(799)		8		10.0
Intellectual property	43		(24)		19		5.0
Total intangible assets	$	11,449	$	(9,282)	$	2,167

Amortization expense for the three and nine months ended September 30, 2023 was $154 and $467, respectively. Amortization expense for the three and nine months ended September 30, 2022 was $197 and $595, respectively. At September 30, 2023, estimated future amortization expense for intangible assets is as follows:

For the remainder of the year ending December 31, 2023	$	81
Fiscal year:
2024	267
2025	267
2026	239
2027	238
Thereafter	608
	$	1,700

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Goodwill

9 Months Ended

Sep. 30, 2023

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill

Goodwill

The following table summarizes the changes in goodwill, if any, by reporting segment from the beginning of the period to the end of the period:

	RNG Fuel		Fuel Station Services		Total
Balance at December 31, 2022	$	51,155	$	3,453	$	54,608
Balance at September 30, 2023	$	51,155	$	3,453	$	54,608

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Borrowings

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Borrowings

BorrowingsThe following table summarizes the borrowings under the various debt facilities as of September 30, 2023 and December 31, 2022:

	September 30, 2023		December 31, 2022
Senior Secured Credit Facility, term loan	$	—	$	15,250
Less: unamortized debt issuance costs	—		—
Less: current portion	—		(15,250)
Senior Secured Credit Facility, term loan, net of debt issuance costs	—		—
Senior Secured Credit Facility, working capital facility	—		7,500
Less: current portion	—		(7,500)
Senior Secured Credit Facility, working capital facility	—		—
OPAL Term Loan	164,118		96,090
Less: unamortized debt issuance costs	(10,492)		(1,758)
Less: current portion	—		(27,732)
OPAL Term Loan, net of debt issuance costs	153,626		66,600
Sunoma Loan	23,000		23,000
Less: unamortized debt issuance costs	(859)		(908)
Less: current portion	(1,739)		(380)
Sunoma Loan, net of debt issuance costs	20,402		21,712
Convertible Note Payable	—		28,528
Less: current portion	—		(28,528)
Convertible Note Payable	—		—
Municipality Loan	—		76
Less: current portion	—		(76)
Municipality Loan	—		—
Non-current borrowings total	$	174,028	$	88,312

As of September 30, 2023, principal maturities of debt are expected as follows, excluding any subsequent refinancing transactions and any undrawn debt facilities as of the date of the condensed consolidated balance sheets:

	OPAL Term Loan		Sunoma Loan		Total
For the remainder of the year ending December 31, 2023	$	—	$	533	$	533
Fiscal year:
2024	—		1,620		1,620
2025	14,771		1,756		16,527
2026	19,694		1,898		21,592
2027	129,653		17,193		146,846
	$	164,118	$	23,000	$	187,118

Senior Secured Credit Facility

On March 20, 2023, the Company repaid in full the remaining outstanding loan under this facility.

On September 21, 2015, FM3, an indirect wholly-owned subsidiary of the Company, entered into a senior secured credit facility (the "Senior Secured Credit Facility") as a borrower and a syndicate of lenders, which provided for an aggregate principal amount of $150,000, consisting of (i) a term loan of $125,000, (ii) a working capital letter of credit facility of up to $19,000 and (iii) a debt service reserve and liquidity facility of up to $6,000. The Company paid $14,300 to the lenders in connection with the transaction.

The loans under the Senior Secured Credit Facility had an interest rate of a fixed margin plus the secured overnight financing rate ("SOFR") for the relevant interest period. The fixed margin is 2.75% for the first four years, then 3.0% until October 8, 2021, and 3.25% thereafter.

On December 19, 2022, FM3 entered into an Omnibus and Consent Agreement (the “FM3 Amendment”). The FM3 Amendment amended the credit agreement, among other things, to (a) extend the maturity date of the obligations thereunder from December 20, 2022 to March 20, 2023, (b) permit OPAL Fuels to purchase the rights and obligations of certain exiting lenders at par, (c) prepay a portion of the outstanding loans made by the remaining lenders and (d) permit the release of certain project company subsidiaries of FM3 from the collateral securing the obligations under the credit agreement. Upon consummation of the FM3 Amendment, the Company repaid $54,929 of the outstanding term loan.

Patronage dividends

The Company is eligible to receive annual patronage dividends from one of its lenders, Cobank ACB under a profit sharing program. For the three and nine months ended September 30, 2023 and 2022, the Company received cash dividends of $126 and $126, respectively, which were recorded as credits to interest expense in the condensed consolidated statements of operations. Additionally, the Company recorded $489 as a long-term asset in the condensed consolidated balance sheets at September 30, 2023 and December 31, 2022, which represents the Company's equity interest in Cobank SCB. These interests will be redeemed for cash beginning in 2024.

OPAL Term Loan

On October 22, 2021, OPAL Fuels Intermediate Holding Company LLC (“OPAL Intermediate Holdco”), an indirect wholly-owned subsidiary of the Company, entered into a $125,000 term loan agreement (the "OPAL Term Loan") with a syndicate of lenders. As of September 1, 2023, the total outstanding balance on the debt facility was $87,602.

On September 1, 2023, OPAL Intermediate Holdco restructured its existing credit agreement and entered into a new senior secured credit facility with OPAL Intermediate HoldCo as the Borrower, direct and indirect subsidiaries of the Borrower as guarantors (the “Guarantors”), the lenders party thereto, as lenders, Apterra Infrastructure Capital LLC, Barclays Bank PLC, BofA Securities, Inc., Celtic Bank Corporation, Citibank, N.A., JP Morgan Chase Bank, N.A. Investec Inc. and ICBC Standard Bank PLC, as joint lead arrangers, and Bank of America, N.A., as administrative agent. Four of the existing lenders participated in the new credit facility.

The Credit Agreement provides for up to $450.0 million of initial and delayed draw term loans (with such delayed draw term loans available for up to 18 months after closing) and $50.0 million of revolving loans. On September 1, 2023, the Company drew down $144,118 and repaid (1) Intermediate HoldCo’s existing secured indebtedness in the amount of approximately $87,602 plus accrued interest, (2) certain accrued but unpaid returns in the amount of $15,669 of the paid-in-kind preferred dividend on our Redeemable preferred non-controlling interests, and (3) approximately $30,107 of indebtedness on Convertible Note Payable. Additionally, the Company utilized $9,000 of availability under the revolver loan to provide for the issuance of letters of credit to support the operations of the Borrower and Guarantors. The proceeds from the facility are expected to be used to fund other general corporate purposes of the Borrower and Guarantors. The Company paid transaction fees and expenses in the amount of approximately $10,790. The Company drew down additional $20,000 during the third quarter to fund capital expenditure on construction of our RNG projects.

The outstanding loans under the Credit Agreement initially bear interest at an annual rate of Term SOFR plus 3.5%, increasing by 0.25% per annum during the term. Accrued interest on amounts outstanding under the delayed draw term loan facility must be paid on the last day of each applicable interest period. Commencing after the 18-month delayed draw term loan availability period expires, the outstanding principal amount of the term loans amortizes at a rate of 1% per quarter and the Borrower is obligated to pay a leverage based cash sweep ranging from 25% to 100% of distributable cash of Borrower and the Guarantors, and subject to certain other mandatory prepayment requirements. The term loans and revolving loans mature on September 1, 2028.

The Borrower’s and the Guarantors’ obligations under the Credit Agreement are secured by substantially all of their personal property assets (other than certain excluded assets identified in the Credit Agreement) and by a non-recourse pledge of the membership interests of the Borrower.

The Credit Agreement requires the Borrower to maintain a consolidated debt service coverage ratio of not less than 1.2:1.0, as tested on a trailing four fiscal basis as of the last day of each fiscal quarter during the term commencing with the quarter ending December 31, 2023, and to maintain a consolidated debt to cash flow ratio of not greater than 4.5 to 1.0 during the delayed draw availability period, and not greater than 4.0 to 1.0 thereafter.

The Credit Agreement includes certain customary and project-related affirmative and negative covenants, including restrictions on distributions, and events of default, which include payment defaults breaches of covenants; changes of control materially incorrect or misleading representations or warranties bankruptcy or other events of insolvency and certain project-related defaults. As of September 30, 2023, the Company is in compliance with the financial covenants under the OPAL Term Loan. Additionally, the OPAL Term Loan contains restrictions on distributions and additional indebtedness.

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.

The Company accounted for the above debt restructuring as debt modification for the existing lenders by performing an analysis on a lender by lender basis under ASC 470-50 Debt modifications and exchanges. As a result, the Company recorded debt extinguishment of $953 representing the fees allocated to the lenders who were repaid in full as part of Other income in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023. Additionally, the Company expensed $295 related to third party legal costs as part of Selling, general and administrative expenses in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023.

As of September 30, 2023 and December 31, 2022, the outstanding loan balance (current and non-current) excluding deferred financing costs was $164,118 and $96,090, 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 $20,000. Sunoma paid $635 in financing fees. The loan bears interest at the greater of prime rate plus 3.50%, or 7.75%. The amounts outstanding under the Sunoma Loan are secured by Sunoma's assets.

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. On July 19, 2022, Sunoma completed the conversion of the construction loan into a permanent loan and increased the commitment from $20,000 to $23,000.

The loans under the Sunoma Loan Agreement bear interest at a rate of 7.68% and have a maturity date of July 19, 2033. The Company is required to pay a quarterly amortization of principal of $533 beginning in October 2023.

The significant assets of Sunoma are parenthesized in the condensed consolidated balance sheets as September 30, 2023 and December 31, 2022. See Note 12. Variable Interest Entities for additional information.

Convertible Note Payable

On May 1, 2021, the Company acquired the remaining ownership interests in Beacon and signed an unsecured, contingently convertible note (the "Convertible Note Payable") with ARCC Beacon LLC ("Ares") for a total aggregate amount for $50,000 at an interest rate of 8.00% per annum. The Company had the option to pay interest on the Convertible Note in cash on a quarterly basis or payment-in-kind. The Company chose the option of payment-in-kind interest.

Upon the consummation of the Business Combination, Ares was permitted to choose to convert the total amount outstanding under the Convertible Note to shares of Class A common stock based on a pre-determined conversion formula. Upon completion of the Business Combination in July 2022, Ares elected to convert 50% of the outstanding amount under the Convertible Note to shares of Class A common stock. The Company issued 3,059,533 shares of Class A common stock and redeemed outstanding debt of $30,595.

The Company elected to account for the Convertible Note Payable using the fair value option in accordance with ASC 820, Fair Value Measurement. The fair value was subsequently remeasured on each reporting date and the change in fair value recorded as interest expense in the condensed consolidated statement of operations for each reporting period. The Company repaid the outstanding balance in full on September 1, 2023.

The Company recorded $(436) and $(1,579) as change in fair value of Convertible Note for the three and nine months ended September 30, 2023, respectively. The Company recorded gains of $2,261 and $151 as change in fair value of the Convertible Note Payable for the three and nine months ended September 30, 2022, respectively as interest and financing expense, net.

Municipality Loan

FM3, an indirect wholly-owned subsidiary of the Company, entered into a loan agreement for the construction of an interconnection that was initially funded by the municipality. The Company made payments to a municipality in the amount of $1,600 plus interest at a fixed annual rate of 3.00% through April 1, 2023. The loan was fully repaid in April 2023.

OPAL Term Loan II

On August 4, 2022, OPAL Intermediate Holdco 2 entered into a new Senior Secured Credit Facility (the "OPAL Term Loan II") with a syndicate of lenders. The indebtedness is guaranteed by certain of the direct and indirect subsidiaries of OPAL Intermediate Holdco 2. The OPAL Term Loan II provides for an approximately two-year delayed term loan facility (the "DDTL Facility") of up to a maximum aggregate principal amount of $100,000 and debt service reserve facility (the "DSR Facility") of up to a maximum aggregate principal amount of $5,000. The proceeds of the DDTL Facility are to be used to fund a portion of the construction of the RNG projects owned, either in full or through a joint venture with a third party, by the subsidiary guarantors. The proceeds of the DSR Facility are to be used solely to satisfy the balance to be maintained in the debt service reserve account. In connection with the transaction, the Company paid $2,200 in financing fees to the lenders and incurred $1,376 in third party fees.

On May 30, 2023, OPAL Intermediate Holdco 2 assigned to Paragon its rights and obligations under OPAL Term Loan II. The joint venture partner of Paragon reimbursed the Company $826 as its portion of the transaction costs incurred.

The Company expensed the remaining deferred financing costs of ($1,895) as loss on debt extinguishment in its condensed consolidated statement of operations for the nine months ended September 30, 2023. There were no amounts outstanding under the OPAL Term Loan II as of May 30, 2023.

Interest rates

2023

For the three and nine months ended September 30, 2023, the weighted average effective interest rate including amortization of debt issuance costs on the Senior Secured Credit Facility was 5.6% including a margin plus SOFR. The debt was repaid in full in March 2023.

For the three and nine months ended September 30, 2023, the weighted average effective interest rate including amortization of debt issuance costs on OPAL Term Loan was 9.2% and 8.0%.

For the three and nine months ended September 30, 2023, the interest rate on the Sunoma Loan was 8.00%.

For the three and nine months ended September 30, 2023, the payment-in-kind interest rate on Convertible Note Payable was 8.00%. The loan was fully repaid in September 2023.

2022

For the three and nine months ended September 30, 2022, the weighted average effective interest rate on the Senior Secured Credit Facility including amortization of debt issuance costs on Senior Secured Credit Facility was 6.80% and 5.40% including a margin plus LIBOR.

For the three and nine months ended September 30, 2022, the weighted average effective interest rate on the OPAL Term Loan including amortization of debt issuance costs was 6.40% and 5.20%.

For three and nine months ended September 30, 2022, the interest rate on the Sunoma loan was 7.81% and 9.0%, respectively.

For the three and nine months ended September 30, 2022, the payment-in-kind interest rate on Convertible Note Payable was 8.0%.

For the three and nine months ended September 30, 2022, the weighted average interest rate on the Municipality Loan was 3.00%.

The following table summarizes the Company's total interest expense for the three and nine months ended September 30, 2023 and 2022:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Senior Secured Credit Facility	$	—	$	(1,101)	$	(282)	$	(2,543)
Convertible Note Payable mark-to-market	(436)		2,261		(1,579)		151
Sunoma Loan	(454)		(424)		(1,348)		(1,335)
OPAL Term Loan (1)	(1,634)		(1,107)		(1,653)		(2,850)
Commitment fees and other finance fees	(248)		(401)		(560)		(605)
Amortization of deferred financing cost	(652)		(616)		(1,447)		(1,514)
Interest expense on finance leases	(24)		(15)		(61)		(28)
Interest income	563		613		2,448		1,512
Total interest expense	$	(2,885)	$	(790)	$	(4,482)	$	(7,212)

(1) Excludes $842 and $4,627 of interest capitalized and recorded as part of Property, Plant and Equipment for the three and nine months ended September 30, 2023, respectively.

XML

Leases

9 Months Ended

Sep. 30, 2023

Leases [Abstract]

Leases

Leases

The following are the types of contracts that fall under ASC 842:

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. These are considered to be operating leases with variable consideration. As per ASC 842, the revenue is recognized in the period earned.

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. The Company elected not to reassess the lease classification due to change in criteria under ASC 842 for these two PPAs. There were no amendments to these two contracts after the Adoption Date.

Included in Fuel Station Service revenues are $917 and $2,119 related to the lease portion of the FPAs for the three and nine months ended September 30, 2023, respectively. This includes $856 and $1,906 related to the lease portion of the FPAs for the three and nine months ended September 30, 2022, respectively.

Included in Renewable Power revenues are $223 and $818 related to the lease element of the PPAs for the three and nine months ended September 30, 2023, respectively. Included in Renewable Power revenues are $384 and $1,014 related to the lease element of the PPAs for the three and nine ended September 30, 2022, respectively.

Lessee Contracts

Ground/Site Leases

The Company through various indirectly owned subsidiaries holds site leases on landfills and dairy farms to build RNG generation facilities. Typically, the lease payments over the lease term are immaterial except for three of our RNG facilities including Beacon and two sites at our Central Valley project - MS Digester ("MS") and VS Digester ("VS").

– The lease at the Beacon facility is for 20 years at a monthly rent of $11.

– The lease term for MD and VS is for a period of 20 years from their commercial operation date at a quarterly rent of $125.

On July 5, 2023, the Company through one of its indirectly owned subsidiary entered into a site lease on a dairy farm to build a facility to collect, process and deliver feedstock to an RNG facility. The lease term is 20 years from its commercial operations date at a quarterly rent of $21,250 with a 5% escalator on the calendar quarter in which the fifth anniversary occurs and every fifth anniversary thereafter. The Company recorded $798 as right-of-use operating lease and corresponding lease liability on its condensed consolidated balance sheet as of September 30, 2023 using an incremental borrowing rate of 8.44%,

Additionally, the Company revised the commercial operation date for its leases for MD and VS by 10 months which changed the lease term for both the leases. The Company treated this as a lease modification and increased its right-of-use asset and corresponding lease liability by $280 on its condensed consolidated balance sheet as of September 30, 2023, using the incremental borrowing rate of 8.44%.

Office Lease

The Company entered into a lease for office and warehouse space that became effective upon the termination of the original lease term on January 31, 2018. The term of the lease renewal was 36 months and contained an option to renew for an additional 24 months. In September 2020, the Company exercised this option. In March 2022, the Company entered into an amendment to the lease which extended the lease term till January 2026. The rent for the lease is $26 per month with a built in escalation to $27 from February 1, 2022 to February 1, 2023, $43 from February 1, 2023 - February 1, 2024, $45 from February 1 2024 - February 1, 2025 and $46 for the remaining lease term. The Company accounted for the change in the lease term as a lease modification and reassessed the right-of-use assets and corresponding lease liabilities as of March 31, 2022.

The Company currently shares office space with Fortistar and reimburses Fortistar on a monthly basis at a predetermined rate. The Company determined that this is not a lease under ASC 842 as there is no identifiable asset and the Company does not have the right to control the use of the office space.

The Company determined that the three site leases and the one office lease are operating leases.

Under ASC 842, leases are classified as either finance or operating arrangements, with such classification affecting the pattern and classification of expense recognition in an entity's income statement. For operating leases, ASC 842 requires recognition in an entity’s income statement of a single lease expense, calculated so that the cost of the lease is allocated over the lease term, generally on a straight-line basis. Right-of-use assets represent a right to use the underlying asset for the lease term and the related lease liability represents an obligation to make lease payments pursuant to the contractual terms of the lease agreement.

Based on the above guidance, the lease expense for the site leases is included as part of Cost of sales - RNG Fuel in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022. The lease expense for the office lease is recorded as part of Selling, general and administrative expenses in its condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022.

Vehicle Leases

The Company leases approximately 65 vehicles in our FM3 and OPAL Fuel Station Services subsidiaries. The leases contain repurchase options at the end of the lease term and the sum total of the lease payments represents substantially the fair value of the asset.

Under ASC 842, the Company determined that the vehicle leases are finance leases. For finance leases, ASC 842 requires recognition of amortization of right-of-use asset as part of depreciation and amortization expense and the interest on the finance lease liability as interest expense in the income statement. The Company accordingly recognized its lease expense on the vehicle leases as part of Depreciation, amortization and accretion expense and interest and financing expense, net in the condensed statement of operations for the three and nine months ended September 30, 2023 and 2022.

Lease Disclosures Under ASC 842

The objective of the disclosure requirements under ASC 842 is to enable viewers of an entity’s financial statements to assess the amount, timing and uncertainty of cash flows arising from lease arrangements. In addition to the supplemental qualitative leasing disclosures included above, below are quantitative disclosures that are intended to meet the stated objective of ASC 842.

Right-of-use assets and Lease liabilities as of September 30, 2023 and December 31, 2022 are as follows:

Description	Location in Balance Sheet	September 30, 2023		December 31, 2022
Assets:
Operating leases (1):
Site leases	Right-of-use assets	$	11,287	$	10,338
Office lease	Right-of-use assets	1,081		1,406
		12,368		11,744
Finance leases (1):
Vehicle leases	Property, plant and equipment, net	1,708		1,236
		14,076		12,980
Liabilities (1):
Sites leases	Lease liabilities - current portion	126		181
Office lease	Lease liabilities - current portion	499		449
Vehicle leases	Accrued expenses and other current liabilities	577		449
		1,202		1,079
Sites leases	Lease liabilities - non-current portion	11,168		10,135
Office lease	Lease liabilities - non-current portion	731		1,110
Vehicle leases	Other long-term liabilities	1,131		825
		$	13,030	$	12,070

(1) The Operating lease right-of-use asset and Operating lease liabilities represent the present value of lease payments for the remaining term of the lease. The discount rate used ranged from 2.30% to 8.44%.

The table below presents components of the Company's lease expense for the three and nine months ended September 30, 2023 and 2022:

Description	Location in Statement of Operations	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Operating lease expense for site leases	Cost of sales - RNG Fuel	$	263	$	261	$	789	$	785
Operating lease expense for office lease	Selling, general, administrative expenses	121		121		363		363
Amortization of right-of-use assets - finance leases	Depreciation, amortization and accretion expense	155		81		436		245
Interest expense on lease liabilities - finance leases	Interest and financing expense, net	24		15		61		28
		$	563	$	478	$	1,649	$	1,421

The Company does not have material short term lease expense for the three and nine months ended September 30, 2023 and 2022.

Weighted average remaining lease term (years)	September 30, 2023
Operating leases	19.1 years
Financing leases	3.1 years
Weighted average discount rate
Operating leases	7.84	%
Financing leases	6.39	%

The table below provides the total amount of lease payments on an undiscounted basis on our lease contracts as of September 30, 2023:

	Site leases			Office leases			Vehicle leases			Total
Discount rate upon adoption	5.4		%	2.3		%	7.6		%
2023	$	261		$	130		$	147		$	538
2024	1,058			540			667			2,265
2025	1,129			562			561			2,252
2026	1,129			47			406			1,582
2027 and beyond	20,145			—			115			20,260
	23,722			1,279			1,896			26,897
Present value of lease liability	11,294			1,230			1,708			14,232
Lease liabilities - current portion	126			499			577			1,202
Lease liabilities - non-current portion	11,168			731			1,131			13,030
Total lease liabilities	$	11,294		$	1,230		$	1,708		$	14,232
Discount based on incremental borrowing rate	$	12,428		$	49		$	188		$	12,665

Leases

Leases

The following are the types of contracts that fall under ASC 842:

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. These are considered to be operating leases with variable consideration. As per ASC 842, the revenue is recognized in the period earned.

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. The Company elected not to reassess the lease classification due to change in criteria under ASC 842 for these two PPAs. There were no amendments to these two contracts after the Adoption Date.

Included in Fuel Station Service revenues are $917 and $2,119 related to the lease portion of the FPAs for the three and nine months ended September 30, 2023, respectively. This includes $856 and $1,906 related to the lease portion of the FPAs for the three and nine months ended September 30, 2022, respectively.

Included in Renewable Power revenues are $223 and $818 related to the lease element of the PPAs for the three and nine months ended September 30, 2023, respectively. Included in Renewable Power revenues are $384 and $1,014 related to the lease element of the PPAs for the three and nine ended September 30, 2022, respectively.

Lessee Contracts

Ground/Site Leases

The Company through various indirectly owned subsidiaries holds site leases on landfills and dairy farms to build RNG generation facilities. Typically, the lease payments over the lease term are immaterial except for three of our RNG facilities including Beacon and two sites at our Central Valley project - MS Digester ("MS") and VS Digester ("VS").

– The lease at the Beacon facility is for 20 years at a monthly rent of $11.

– The lease term for MD and VS is for a period of 20 years from their commercial operation date at a quarterly rent of $125.

On July 5, 2023, the Company through one of its indirectly owned subsidiary entered into a site lease on a dairy farm to build a facility to collect, process and deliver feedstock to an RNG facility. The lease term is 20 years from its commercial operations date at a quarterly rent of $21,250 with a 5% escalator on the calendar quarter in which the fifth anniversary occurs and every fifth anniversary thereafter. The Company recorded $798 as right-of-use operating lease and corresponding lease liability on its condensed consolidated balance sheet as of September 30, 2023 using an incremental borrowing rate of 8.44%,

Additionally, the Company revised the commercial operation date for its leases for MD and VS by 10 months which changed the lease term for both the leases. The Company treated this as a lease modification and increased its right-of-use asset and corresponding lease liability by $280 on its condensed consolidated balance sheet as of September 30, 2023, using the incremental borrowing rate of 8.44%.

Office Lease

The Company entered into a lease for office and warehouse space that became effective upon the termination of the original lease term on January 31, 2018. The term of the lease renewal was 36 months and contained an option to renew for an additional 24 months. In September 2020, the Company exercised this option. In March 2022, the Company entered into an amendment to the lease which extended the lease term till January 2026. The rent for the lease is $26 per month with a built in escalation to $27 from February 1, 2022 to February 1, 2023, $43 from February 1, 2023 - February 1, 2024, $45 from February 1 2024 - February 1, 2025 and $46 for the remaining lease term. The Company accounted for the change in the lease term as a lease modification and reassessed the right-of-use assets and corresponding lease liabilities as of March 31, 2022.

The Company currently shares office space with Fortistar and reimburses Fortistar on a monthly basis at a predetermined rate. The Company determined that this is not a lease under ASC 842 as there is no identifiable asset and the Company does not have the right to control the use of the office space.

The Company determined that the three site leases and the one office lease are operating leases.

Under ASC 842, leases are classified as either finance or operating arrangements, with such classification affecting the pattern and classification of expense recognition in an entity's income statement. For operating leases, ASC 842 requires recognition in an entity’s income statement of a single lease expense, calculated so that the cost of the lease is allocated over the lease term, generally on a straight-line basis. Right-of-use assets represent a right to use the underlying asset for the lease term and the related lease liability represents an obligation to make lease payments pursuant to the contractual terms of the lease agreement.

Based on the above guidance, the lease expense for the site leases is included as part of Cost of sales - RNG Fuel in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022. The lease expense for the office lease is recorded as part of Selling, general and administrative expenses in its condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022.

Vehicle Leases

The Company leases approximately 65 vehicles in our FM3 and OPAL Fuel Station Services subsidiaries. The leases contain repurchase options at the end of the lease term and the sum total of the lease payments represents substantially the fair value of the asset.

Under ASC 842, the Company determined that the vehicle leases are finance leases. For finance leases, ASC 842 requires recognition of amortization of right-of-use asset as part of depreciation and amortization expense and the interest on the finance lease liability as interest expense in the income statement. The Company accordingly recognized its lease expense on the vehicle leases as part of Depreciation, amortization and accretion expense and interest and financing expense, net in the condensed statement of operations for the three and nine months ended September 30, 2023 and 2022.

Lease Disclosures Under ASC 842

The objective of the disclosure requirements under ASC 842 is to enable viewers of an entity’s financial statements to assess the amount, timing and uncertainty of cash flows arising from lease arrangements. In addition to the supplemental qualitative leasing disclosures included above, below are quantitative disclosures that are intended to meet the stated objective of ASC 842.

Right-of-use assets and Lease liabilities as of September 30, 2023 and December 31, 2022 are as follows:

Description	Location in Balance Sheet	September 30, 2023		December 31, 2022
Assets:
Operating leases (1):
Site leases	Right-of-use assets	$	11,287	$	10,338
Office lease	Right-of-use assets	1,081		1,406
		12,368		11,744
Finance leases (1):
Vehicle leases	Property, plant and equipment, net	1,708		1,236
		14,076		12,980
Liabilities (1):
Sites leases	Lease liabilities - current portion	126		181
Office lease	Lease liabilities - current portion	499		449
Vehicle leases	Accrued expenses and other current liabilities	577		449
		1,202		1,079
Sites leases	Lease liabilities - non-current portion	11,168		10,135
Office lease	Lease liabilities - non-current portion	731		1,110
Vehicle leases	Other long-term liabilities	1,131		825
		$	13,030	$	12,070

(1) The Operating lease right-of-use asset and Operating lease liabilities represent the present value of lease payments for the remaining term of the lease. The discount rate used ranged from 2.30% to 8.44%.

The table below presents components of the Company's lease expense for the three and nine months ended September 30, 2023 and 2022:

Description	Location in Statement of Operations	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Operating lease expense for site leases	Cost of sales - RNG Fuel	$	263	$	261	$	789	$	785
Operating lease expense for office lease	Selling, general, administrative expenses	121		121		363		363
Amortization of right-of-use assets - finance leases	Depreciation, amortization and accretion expense	155		81		436		245
Interest expense on lease liabilities - finance leases	Interest and financing expense, net	24		15		61		28
		$	563	$	478	$	1,649	$	1,421

The Company does not have material short term lease expense for the three and nine months ended September 30, 2023 and 2022.

Weighted average remaining lease term (years)	September 30, 2023
Operating leases	19.1 years
Financing leases	3.1 years
Weighted average discount rate
Operating leases	7.84	%
Financing leases	6.39	%

The table below provides the total amount of lease payments on an undiscounted basis on our lease contracts as of September 30, 2023:

	Site leases			Office leases			Vehicle leases			Total
Discount rate upon adoption	5.4		%	2.3		%	7.6		%
2023	$	261		$	130		$	147		$	538
2024	1,058			540			667			2,265
2025	1,129			562			561			2,252
2026	1,129			47			406			1,582
2027 and beyond	20,145			—			115			20,260
	23,722			1,279			1,896			26,897
Present value of lease liability	11,294			1,230			1,708			14,232
Lease liabilities - current portion	126			499			577			1,202
Lease liabilities - non-current portion	11,168			731			1,131			13,030
Total lease liabilities	$	11,294		$	1,230		$	1,708		$	14,232
Discount based on incremental borrowing rate	$	12,428		$	49		$	188		$	12,665

Leases

Leases

The following are the types of contracts that fall under ASC 842:

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. These are considered to be operating leases with variable consideration. As per ASC 842, the revenue is recognized in the period earned.

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. The Company elected not to reassess the lease classification due to change in criteria under ASC 842 for these two PPAs. There were no amendments to these two contracts after the Adoption Date.

Included in Fuel Station Service revenues are $917 and $2,119 related to the lease portion of the FPAs for the three and nine months ended September 30, 2023, respectively. This includes $856 and $1,906 related to the lease portion of the FPAs for the three and nine months ended September 30, 2022, respectively.

Included in Renewable Power revenues are $223 and $818 related to the lease element of the PPAs for the three and nine months ended September 30, 2023, respectively. Included in Renewable Power revenues are $384 and $1,014 related to the lease element of the PPAs for the three and nine ended September 30, 2022, respectively.

Lessee Contracts

Ground/Site Leases

The Company through various indirectly owned subsidiaries holds site leases on landfills and dairy farms to build RNG generation facilities. Typically, the lease payments over the lease term are immaterial except for three of our RNG facilities including Beacon and two sites at our Central Valley project - MS Digester ("MS") and VS Digester ("VS").

– The lease at the Beacon facility is for 20 years at a monthly rent of $11.

– The lease term for MD and VS is for a period of 20 years from their commercial operation date at a quarterly rent of $125.

On July 5, 2023, the Company through one of its indirectly owned subsidiary entered into a site lease on a dairy farm to build a facility to collect, process and deliver feedstock to an RNG facility. The lease term is 20 years from its commercial operations date at a quarterly rent of $21,250 with a 5% escalator on the calendar quarter in which the fifth anniversary occurs and every fifth anniversary thereafter. The Company recorded $798 as right-of-use operating lease and corresponding lease liability on its condensed consolidated balance sheet as of September 30, 2023 using an incremental borrowing rate of 8.44%,

Additionally, the Company revised the commercial operation date for its leases for MD and VS by 10 months which changed the lease term for both the leases. The Company treated this as a lease modification and increased its right-of-use asset and corresponding lease liability by $280 on its condensed consolidated balance sheet as of September 30, 2023, using the incremental borrowing rate of 8.44%.

Office Lease

The Company entered into a lease for office and warehouse space that became effective upon the termination of the original lease term on January 31, 2018. The term of the lease renewal was 36 months and contained an option to renew for an additional 24 months. In September 2020, the Company exercised this option. In March 2022, the Company entered into an amendment to the lease which extended the lease term till January 2026. The rent for the lease is $26 per month with a built in escalation to $27 from February 1, 2022 to February 1, 2023, $43 from February 1, 2023 - February 1, 2024, $45 from February 1 2024 - February 1, 2025 and $46 for the remaining lease term. The Company accounted for the change in the lease term as a lease modification and reassessed the right-of-use assets and corresponding lease liabilities as of March 31, 2022.

The Company currently shares office space with Fortistar and reimburses Fortistar on a monthly basis at a predetermined rate. The Company determined that this is not a lease under ASC 842 as there is no identifiable asset and the Company does not have the right to control the use of the office space.

The Company determined that the three site leases and the one office lease are operating leases.

Under ASC 842, leases are classified as either finance or operating arrangements, with such classification affecting the pattern and classification of expense recognition in an entity's income statement. For operating leases, ASC 842 requires recognition in an entity’s income statement of a single lease expense, calculated so that the cost of the lease is allocated over the lease term, generally on a straight-line basis. Right-of-use assets represent a right to use the underlying asset for the lease term and the related lease liability represents an obligation to make lease payments pursuant to the contractual terms of the lease agreement.

Based on the above guidance, the lease expense for the site leases is included as part of Cost of sales - RNG Fuel in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022. The lease expense for the office lease is recorded as part of Selling, general and administrative expenses in its condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022.

Vehicle Leases

The Company leases approximately 65 vehicles in our FM3 and OPAL Fuel Station Services subsidiaries. The leases contain repurchase options at the end of the lease term and the sum total of the lease payments represents substantially the fair value of the asset.

Under ASC 842, the Company determined that the vehicle leases are finance leases. For finance leases, ASC 842 requires recognition of amortization of right-of-use asset as part of depreciation and amortization expense and the interest on the finance lease liability as interest expense in the income statement. The Company accordingly recognized its lease expense on the vehicle leases as part of Depreciation, amortization and accretion expense and interest and financing expense, net in the condensed statement of operations for the three and nine months ended September 30, 2023 and 2022.

Lease Disclosures Under ASC 842

The objective of the disclosure requirements under ASC 842 is to enable viewers of an entity’s financial statements to assess the amount, timing and uncertainty of cash flows arising from lease arrangements. In addition to the supplemental qualitative leasing disclosures included above, below are quantitative disclosures that are intended to meet the stated objective of ASC 842.

Right-of-use assets and Lease liabilities as of September 30, 2023 and December 31, 2022 are as follows:

Description	Location in Balance Sheet	September 30, 2023		December 31, 2022
Assets:
Operating leases (1):
Site leases	Right-of-use assets	$	11,287	$	10,338
Office lease	Right-of-use assets	1,081		1,406
		12,368		11,744
Finance leases (1):
Vehicle leases	Property, plant and equipment, net	1,708		1,236
		14,076		12,980
Liabilities (1):
Sites leases	Lease liabilities - current portion	126		181
Office lease	Lease liabilities - current portion	499		449
Vehicle leases	Accrued expenses and other current liabilities	577		449
		1,202		1,079
Sites leases	Lease liabilities - non-current portion	11,168		10,135
Office lease	Lease liabilities - non-current portion	731		1,110
Vehicle leases	Other long-term liabilities	1,131		825
		$	13,030	$	12,070

(1) The Operating lease right-of-use asset and Operating lease liabilities represent the present value of lease payments for the remaining term of the lease. The discount rate used ranged from 2.30% to 8.44%.

The table below presents components of the Company's lease expense for the three and nine months ended September 30, 2023 and 2022:

Description	Location in Statement of Operations	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Operating lease expense for site leases	Cost of sales - RNG Fuel	$	263	$	261	$	789	$	785
Operating lease expense for office lease	Selling, general, administrative expenses	121		121		363		363
Amortization of right-of-use assets - finance leases	Depreciation, amortization and accretion expense	155		81		436		245
Interest expense on lease liabilities - finance leases	Interest and financing expense, net	24		15		61		28
		$	563	$	478	$	1,649	$	1,421

The Company does not have material short term lease expense for the three and nine months ended September 30, 2023 and 2022.

Weighted average remaining lease term (years)	September 30, 2023
Operating leases	19.1 years
Financing leases	3.1 years
Weighted average discount rate
Operating leases	7.84	%
Financing leases	6.39	%

The table below provides the total amount of lease payments on an undiscounted basis on our lease contracts as of September 30, 2023:

	Site leases			Office leases			Vehicle leases			Total
Discount rate upon adoption	5.4		%	2.3		%	7.6		%
2023	$	261		$	130		$	147		$	538
2024	1,058			540			667			2,265
2025	1,129			562			561			2,252
2026	1,129			47			406			1,582
2027 and beyond	20,145			—			115			20,260
	23,722			1,279			1,896			26,897
Present value of lease liability	11,294			1,230			1,708			14,232
Lease liabilities - current portion	126			499			577			1,202
Lease liabilities - non-current portion	11,168			731			1,131			13,030
Total lease liabilities	$	11,294		$	1,230		$	1,708		$	14,232
Discount based on incremental borrowing rate	$	12,428		$	49		$	188		$	12,665

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Derivative Financial Instruments and Fair Value Measurements

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Financial Instruments and Fair Value Measurements

Derivative Financial Instruments and Fair Value Measurements

Interest Rate Swaps

During August 2022, the Company entered into two interest rate swaps for the notional amount of $61,926 of the OPAL Term Loan II at a fixed interest rate of 2.47% to hedge the SOFR-based floating interest rate. On August 16, 2022, the Company entered into a swaption for a notional amount of $13,074 with fixed rate of 2.32% with a maturity date of May 31, 2023. The Company accounted for the swaption as an economic hedge and included the change in the fair market value in the condensed consolidated statement of operations.

The two interest rate swaps were designated and qualified as cash flow hedges. The Company uses interest rate swaps for the management of interest rate risk exposure, as an interest rate swap effectively converts a portion of the Company’s debt from a floating to a fixed rate. The interest rate swap is an agreement between the Company and counterparties to pay, in the future, a fixed-rate payment in exchange for the counterparties paying the Company a variable payment. The amount of the net payment obligation is based on the notional amount of the interest rate swap and the prevailing market interest rates. The Company may terminate the interest rate swaps prior to their expiration dates, at which point a realized gain or loss may be recognized, or may be amortized over the original life of the interest rate swap if the hedged debt remains outstanding. The value of the Company’s commitment would increase or decrease based primarily on the extent to which interest rates move against the rate fixed for each swap.

The Company records the fair value of the interest rate swap as an asset or liability on its balance sheet. The effective portion of the swap is recorded in Accumulated other comprehensive income.

On May 30, 2023, OPAL Intermediate Holdco 2, assigned to Paragon its rights and obligations under the OPAL Term Loan II. Concurrently, the Company terminated the two interest rate swaps outstanding under this loan and received $812 as settlement from the swap counterparty. Paragon entered into four interest rate swaps for a notional amount of $56,914 at a fixed interest rate of 3.52%. The Company terminated the swaption on the same date.

After the transaction, the Company recognized a gain of $812 in the condensed consolidated statement of operations for the nine months ended September 30, 2023 as part of Change in fair value of derivative instruments. The Company received $136 as a settlement from the swaption counterparty and recognized $46 as loss on termination of the swaption as part of change in fair value of derivative instruments. Additionally, the Company recognized $515 as its share of the Accumulated other comprehensive income from Paragon and increased its basis in equity method investment on its condensed consolidated balance sheet as of September 30, 2023.

The following table summarizes the interest rate swaps in place as of September 30, 2023 and December 31, 2022:

Interest rate swap detail					Notional Amount
Trade date	Fixed rate		Start date	End date	September 30, 2023		December 31, 2022
August 15, 2022	2.47	%	June 28, 2024	August 4, 2027	$	—	41,284
August 15, 2022	2.47	%	June 28, 2024	August 4, 2027	—		20,642
					$	—	$	61,926

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

	September 30, 2023		December 31, 2022		Location of Fair Value Recognized in Balance Sheet
Derivatives designated as economic hedges:
Current portion of swaption	$	—	$	182	Derivative financial assets, current portion
Derivatives designated as cash flow hedges:
Long term portion of the interest rate swaps	—		954		Derivative financial assets, non-current
	$	—	$	1,136

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

	Three Months Ended September 30,				Nine Months Ended September 30,				Location of (Loss) Gain Recognized in Operations from Derivatives
	2023		2022		2023		2022
Interest rate swaps	$	—	$	1,580	$	—	$	954
Swaption	—		246		(46)		246
Net periodic settlements	—		(1,631)		812		(677)
	$	—	$	195	$	766	$	523	Change in fair value of derivative instruments, net

The following table summarizes the fair value of derivative instruments on the Company's condensed consolidated balance sheets and the effect of netting arrangements and collateral on its financial position:

	Gross Amounts of Recognized Assets		Gross Amounts Offset in the Balance Sheet		Net Amounts of Assets in the Balance Sheet
Balance, September 30, 2023:
Interest rate swap asset	$	—	$	—	$	—
Swaption asset	—		—		—
	$	—	$	—	$	—
Balance, December 31, 2022:
Interest rate swap asset	$	954	$	—	$	954
Swaption asset	182		—		182
	$	1,136	$	—	$	1,136

Commodity Swap Contracts

The Company utilizes commodity swap contracts to hedge against the unfavorable price fluctuations in market prices of electricity. The Company does not apply hedge accounting to these contracts. As such, unrealized and realized gain (loss) is recognized as a component of Renewable Power revenues in the condensed consolidated statement of operations and Derivative financial asset — current and non-current in the condensed consolidated balance sheets. These are considered to be Level 2 instruments in the fair value hierarchy. By using commodity swaps, the Company exposes itself to credit risk and market risk. Credit risk is the failure of the counterparty to perform under the terms of the swap contract. When the fair value of the swap contract is positive, the counterparty owes the Company creating a credit risk. The Company manages the credit risk by entering into contracts with financially sound counterparties. To mitigate this risk, management monitors counterparty credit exposure on an annual basis, and the necessary credit adjustments have been reflected in the fair value of financial derivative instruments. When the fair value of the swap contract is negative, the Company owes the counterparty creating a market risk that the market price is higher than the contract price resulting in the Company not participating in the opportunity to earn higher revenues.

In December 2018, the Company signed an amendment that converted an existing PPA into a commodity swap contract to allow the Company flexibility to sell the capacity separately and schedule the sale of electricity to independent third parties. Following the amendment, the Company agreed to net settle the contract in cash on a monthly basis based on the difference between the contract price and market price. The contract has a default minimum of 34,554 MWh per year. Additionally, the Company entered into an ISDA agreement with a counterparty in November 2019. Pursuant to the agreement, the Company entered into swaps with contract prices ranging between $35.75 and $51.25 per MWh.

The following table summarizes the commodity swaps in place as of September 30, 2023 and December 31, 2022. There were no new commodity swap contracts entered during the three months ended September 30, 2023.

Trade Date	Period From	Period To	Notional Quantity per Year (“MWh”)	Average Contract Price (per MWh)
October 17, 2022	January 1, 2023	December 31, 2024	70,176	$	68.50
October 17, 2022	January 1, 2023	December 31, 2024	26,280	$	65.50
November 17, 2022	January 1, 2023	December 31, 2024	35,088	$	81.50

The following table summarizes the effect of commodity swaps on the condensed consolidated statements of operations for the three and nine months ended September 30, 2023 and 2022:

Derivatives not designated as hedging instruments	Location of (loss) gain recognized	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Commodity swaps - realized (loss) gain	Revenues - Renewable power	$	493	$	(744)	$	1,373	$	(931)
Commodity swaps - unrealized gain (loss)	Revenues - Renewable power	(30)		161		733		(775)
Total realized and unrealized gain (loss)	Revenues - Renewable power	$	463	$	(583)	$	2,106	$	(1,706)

The following table summarizes the derivative assets and liabilities related to commodity swaps as of September 30, 2023 and December 31, 2022:

	Fair Value				Location of Fair value recognized in Balance Sheet
	September 30, 2023		December 31, 2022
Derivatives designated as economic hedges
Current portion of unrealized gain on commodity swaps	$	486	$	—	Derivative financial asset, current portion
Non-current portion of unrealized gain on commodity swaps	$	117	$	—	Derivative financial asset, non-current portion
Current portion of unrealized loss on commodity swaps	$	—	$	(130)	Derivative financial liability, current portion

Other Derivative Liabilities

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 September 30, 2023 and 2022:

Derivative liability	Three Months Ended September 30,				Nine Months Ended September 30,				Location of (Loss) Gain Recognized in Operations from Derivatives
	2023		2022		2023		2022
Put option to Meteora	$	—	$	384	$	(311)	$	384
Sponsor Earnout Awards	(338)		1,100		(201)		1,100
OPAL Earnout Awards	200		5,300		4,701		5,300
Public Warrants	—		(3,578)		—		(3,578)
Private Warrants	—		(5,309)		—		(5,309)
	$	(138)	$	(2,103)	$	4,189	$	(2,103)	Change in fair value of derivative instruments, net

Fair Value Measurements

The fair value of financial instruments, including long-term debt and derivative instruments is defined as the amount at which the instruments could be exchanged in a current transaction between willing parties. 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 is considered Level 2 in the fair value hierarchy, of $174,028 and $88,312 as of September 30, 2023 and December 31, 2022, respectively, represents the total amount to be repaid if the debt has to be discharged in full and therefore approximates its fair value.

The Company follows ASC 820, Fair Value Measurement, regarding fair value measurements which establishes a three-tier fair value hierarchy and prioritizes the inputs used in valuation techniques that measure fair value. These tiers include:

Level 1 — defined as observable inputs such as quoted prices for identical instruments in active markets;

Level 2 — defined as quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, or model-derived valuations for which all significant inputs are observable market data;

Level 3 — defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions.

Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company's assessment of the significance of an input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

The Company values its energy commodity swap contracts based on the applicable geographical market energy forward curve. The forward curves are derived based on the quotes provided by New York Mercantile Exchange, Amerex Energy Services and Tradition Energy. The Company does not consider that the pricing index used involves significant judgement on the part of management. Therefore, the Company classifies these commodity swap contracts within Level 2 of the valuation hierarchy based on the observable market rates used to determine fair value.

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 estimates the fair value of asset retirement obligations by calculating the estimated present value of the cost to retire the asset. This estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental, and political environments. In addition, the Company determines the Level 3 fair value measurements based on historical information and current market conditions. These assumptions represent Level 3 inputs, which can regularly change. As such, the fair value measurement of asset retirement obligations is subject to changes in these unobservable inputs as of the measurement date. The Company used a discounted cash flow model in which cash outflows estimated to retire the asset are discounted to their present value using an expected discount rate. A significant increase (decrease) in the discount rate in isolation could result in a significantly lower (higher) fair value measurement. The Company estimated the fair value of its asset retirement obligations based on discount rates ranging from 5.75% to 8.5%.

The Company accounted for the Convertible Note Payable at fair value at each reporting period. As of September 30, 2023, the Convertible Note Payable was repaid in full. As of December 31, 2022, the Company recorded the Convertible Note Payable at par plus accrued interest as it is payable on demand by either party and therefore represents fair value.

The fair value of the Sponsor Earnout Awards as of September 30, 2023 was determined using a Monte Carlo valuation model with a distribution of potential outcomes on a daily basis over the four-year post-close period. Assumptions used in the valuation are as follows:

• Current stock price — The Company's closing stock price of $8.20 as of September 30, 2023;

• Expected volatility —55% 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 — 4.72% 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 3.8 year term of the earnout period;

•Dividend yield - zero.

The fair value of the OPAL Earnout Awards as of September 30, 2023 was determined using a Monte Carlo valuation model with a distribution of potential outcomes for stock price and EBITDA over the 2-year period commencing on January 1, 2023 and ending on December 31, 2024. Assumptions used in the valuation are as follows:

• Current stock price — The Company's closing stock price of $8.20 as of September 30, 2023;

•Weighted average cost of capital - 16% based on an average of historical volatilities of selected industry peers deemed to be comparable to our business.

•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 — 5.5% 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 1.5 year term of the earnout period;

•Dividend yield - zero.

There were no transfers of assets between Level 1, Level 2, or Level 3 of the fair value hierarchy as of September 30, 2023.

The Company's assets and liabilities that are measured at fair value on a recurring basis include the following as of September 30, 2023 and December 31, 2022, set forth by level, within the fair value hierarchy:

	Fair value as of September 30, 2023
	Level 1		Level 2		Level 3		Total
Liabilities:
Asset retirement obligation	$	—	$	—	$	6,563	$	6,563
Earnout liabilities	—		—		4,291		4,291
Assets:
Short term investments	18,028		—		—		18,028
Commodity swap contracts	—		603		—		603

	Fair value as of December 31, 2022
	Level 1		Level 2		Level 3		Total
Liabilities:
Asset retirement obligation	$	—	$	—	$	6,256	$	6,256
Convertible Note Payable (1)	—		28,528				28,528
Put option with Meteora	—		—		4,466		4,466
Commodity swap contracts	—		130		—		130
Earnout liabilities	—		—		8,790		8,790
Assets:
Short term investments	64,976		—		—		64,976
Swaption	—		182		—		182
Commodity swap contracts	—		954		—		954

(1) The fair value of the Convertible Note Payable as of December 31, 2022, represents the outstanding principal and paid-in-kind interest. Therefore it did not have any unobservable inputs which required the Company to develop its own assumptions. The methodology for calculating the fair value has changed as of December 31, 2022 as the prepayment penalty was cancelled upon consummation of Business Combination. Therefore, the Convertible Note Payable has been transferred from Level 3 to Level 2.

A summary of changes in the fair values of the Company’s Level 3 instruments, attributable to asset retirement obligations, for the nine months ended September 30, 2023 is included in Note 2, Summary of Significant Accounting Policies.

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Related Parties

9 Months Ended

Sep. 30, 2023

Related Party Transactions [Abstract]

Related Parties

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

Sale of Non-Controlling Interests to Related Parties

On November 29, 2021, as part of an exchange agreement, OPAL Fuels issued 14 newly authorized common units and 300,000 Series A-1 preferred units to Hillman in return for Hillman’s non-controlling interest in four RNG project subsidiaries for total consideration of $30,000. Upon the consummation of the Business Combination, the Series A-1 preferred units have been converted to Redeemable preferred non-controlling interests. The Company recorded paid-in-kind preferred dividends of $656 and $1,986 for the three and nine months ended September 30, 2023, respectively. The Company recorded paid-in-kind preferred dividends of $613 and $1,820 for the three and nine months ended September 30, 2022, respectively. The Company repaid all outstanding paid-in-kind preferred dividends as of September 30, 2023. Please see Note 13. Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Deficit, for additional information.

Issuance of Redeemable preferred non-controlling interests

On November 29, 2021, NextEra subscribed for up to 1,000,000 Series A preferred units, which are 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. The Company recorded paid-in-kind preferred dividends of $2,126 and $6,408 for the three and nine months ended September 30, 2023, respectively. The Company recorded paid-in-kind preferred dividends of $2,045 and $3,273 for the three and nine months ended September 30, 2022, respectively. The Company repaid all outstanding paid-in-kind preferred dividends as of September 30, 2023. Please see Note 13. Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' deficit, for additional information.

Purchase and Sale agreement for Environmental Attributes

On November 29, 2021, the Company entered into a Purchase and Sale agreement with NextEra for the Environmental Attributes generated by the RNG Fuels business. Under this agreement, the Company plans to sell a minimum of 90% of the Environmental Attributes generated and will receive net proceeds based on the agreed upon price less a specified discount. A specified volume of Environmental Attributes sold per quarter will incur a fee per Environmental Attribute in addition to the specified discount. The agreement was effective beginning January 1, 2022. For the three and nine months ended September 30, 2023, the Company earned net revenues after discount and fees of $25,724 and $43,784, respectively, under this contract which were recorded as part of Revenues - RNG fuel and Fuel Station Services. For the three and nine months ended September 30, 2022, the Company earned net revenues after discount and fees of $19,336 and $49,024, respectively, which were recorded as part of Revenues - RNG fuel and Fuel Station Services. Please see Note 2. Summary of Significant Accounting Policies for additional information.

Commodity Swap Contracts Under ISDA

The Company entered into an ISDA agreement with NextEra in November 2019. Pursuant to the agreement, the Company enters into commodity swap contracts on a periodic basis. As of September 30, 2023 and December 31, 2022, there were three commodity swap contracts outstanding. The Company records the realized and unrealized gain (loss) on these commodity swap contracts as part of Revenues - Renewable Power. Please see Note 9. Derivative Financial Instruments and Fair Value Measurements for additional information. The Company recorded $1,732 and $927 as revenues earned under the commodity swap contracts for the three months ended September 30, 2023 and 2022. The Company recorded $5,006 and $3,196 as revenues earned under the commodity swap contracts for the nine months ended September 30, 2023 and 2022.

Purchase Of Investments From Related Parties

In August 2021, the Company acquired 100% of the ownership interests in Reynolds, an RNG production facility for $12,020 which was funded with cash on hand. Reynolds held an equity investment of 1,570 Class B units in GREP representing 20% interest for a cash consideration of $1,570 which owns 50% of Biotown, a power generation facility under development to convert to an RNG facility. The Reynolds transaction was an asset acquisition from an affiliate under common control. The Company accounts for its 20% equity investment in GREP under the equity method. The Company recorded a net loss of $374 and net income of $3,034 as its share of net (loss) income for the three months ended September 30, 2023 and 2022, respectively. The Company recorded a net loss of $810 and net income of $2,478 as its share of net (loss) income for the nine months ended September 30, 2023 and 2022, respectively.

Sales Contracts with Related Parties

In August 2020, Fuel Station Services contracted with Sunoma to dispense RNG and to generate and market the resulting RINs and LCFS credits created on behalf of the entity. Additionally, Fuel Station Services contracted with Pine Bend in December 2020 and Noble Road in March 2021 to provide the same services.

These contracts each have term of 10 years. The Company receives non-cash consideration in the form of RINs or LCFSs for providing these services and recognizes the RINs or LCFSs received as inventory based on their estimated fair value at contract inception. The Pine Bend and Noble road facilities came online in the first and third quarter of 2022. Sunoma came online in the fourth quarter of 2021. For the three months ended September 30, 2023 and 2022, the Company earned environmental processing fees of $570 and $80 net of intersegment elimination, which are included in Fuel Station Services revenues in the condensed consolidated statements of operations. For the nine months ended September 30, 2023 and 2022, the Company earned environmental processing fees of $1,711 and $322 net of intersegment elimination, which are included in Fuel Station Services revenues in the condensed consolidated statements of operations.

Service Agreements with Related Parties

On December 31, 2020, OPAL Fuels signed a Management, Operations, and Maintenance Services Agreement (“Administrative Services Agreement”) with Fortistar LLC ("Fortistar"), pursuant to which Fortistar provides management, operations, and maintenance services to the Company. The Administrative Services Agreement expires on December 31, 2023, unless termination occurs earlier due to dissolution of the Company or it is terminated by the Company’s secured lenders in certain circumstances. The Administrative Services Agreement provides for payment of service fees based on actual time incurred at contractually agreed rates, as well as a fixed annual payment of $580 per year adjusted annually for inflation. Additionally, the Administrative Services Agreement provides for the Company to receive credits for any services provided by the Company's employees to Fortistar. For the three and nine months ended September 30, 2023 and 2022, there have been no material services provided by the Company's employees to Fortistar.

In June 2021, the company entered into a Management Services Agreement with Costar Partners LLC (“Costar”), an affiliate of Fortistar. Pursuant to the Management Services Agreement, Costar provides information technology (“IT”) support services, software use, licensing services, management of third party infrastructure and security services and additional IT services as needed by the Company. The Management Services Agreement provides for Costar to be compensated based on actual costs incurred and licensing fees per user for certain software applications. The Management Services Agreement expires in June 2024 unless the termination occurs earlier due to dissolution of the Company or it is terminated by the Company’s secured lenders in certain circumstances.

The following table summarizes the various fees recorded under the agreements described above which are included in "Selling, general, and administrative" expenses:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Staffing and management services	$	414	$	578	$	1,406	$	1,683
Rent - fixed compensation	166		168		494		442
IT services	754		636		2,210		1,721
Total	$	1,334	$	1,382	$	4,110	$	3,846

As of September 30, 2023 and December 31, 2022, the Company had Accounts payable, related party in the amounts of $1,365 and $1,346, respectively.

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Reportable Segments and Geographic Information

9 Months Ended

Sep. 30, 2023

Segment Reporting [Abstract]

Reportable Segments and Geographic Information

Reportable Segments and Geographic InformationThe Company is organized into four operating segments based on the characteristics of its renewable power generation, dispensing portfolio, and the nature of other products and services. During the first quarter of 2023, the Company changed its internal reporting to its Chief Operating Decision Makers to change the composition of revenues

included in our reportable segments. The internal reporting was changed to provide more visibility into our RNG fuel production and operations and to align fuel dispensing revenues with construction and service of fuel dispensing stations. Additionally, the Company changed its internal reporting to report revenues from RECs and ISCC Carbon Credits from RNG Fuel to Renewable Power segment in the current quarter. This is primarily to reflect a strategic business change to identify all revenues earned from environmental attributes generated from Renewable Power facilities in the same segment.

Therefore, the Company reclassified the revenues and the corresponding cost of sales for CNG tolling business which were previously presented as part of Revenues - RNG Fuel and Cost of sales - RNG Fuel to Revenues - Fuel station services and Cost of sales - Fuel station services, respectively. The Company reclassified revenues earned from sale of RECs and ISCC Carbon Credits from Revenues - RNG Fuel to Revenues - Renewable Power. The Company also adjusted the revenues and cost of sales for the prior year period presented for comparison purposes.

For the three months ended September 30, 2023 and 2022, the Company classified revenues from its fuel dispensing business of $16,852 and $12,545, respectively, as part of Revenues - Fuel station services. For the nine months ended September 30, 2023, the Company classified revenues from fuel dispensing business of $35,103 and $31,852, respectively, as part of Revenues - Fuel station services.

For the three months ended September 30, 2023 and 2022, the Company classified revenues from the sale of environmental attributes generated from Renewable Power facilities of $4,539 and $1,543, respectively, as part of Revenues - Renewable Power. For the nine months ended September 30, 2023 and 2022, the Company classified revenues from the sale of environmental attributes generated from Renewable Power facilities of $15,783 and $2,528, respectively, as part of Revenues - Renewable Power.

For the three months ended September 30, 2023 and 2022, the Company classified cost of sales related to fuel dispensing business of $11,703 and $10,088, respectively as part of Cost of sales - Fuel station services. For the nine months ended September 30, 2023 and 2022, the Company classified cost of sales related to the fuel dispensing business of $28,527 and $24,801, respectively as part of Cost of sales - Fuel station services.

We aligned our reportable segments disclosure to align with the information and internal reporting that is provided to our Chief Operating Decision Makers. Therefore, the Company reassessed its reportable segments and revised all the prior periods to make the segment disclosures comparable.

•RNG Fuel. The RNG Fuel segment relates to all RNG supply directly related to the generation and sale of brown gas and environmental credits, and consists of:

◦Development and construction – RNG facilities in which long term gas right contracts have been, or are in the process of being ratified and the construction of RNG generation facilities.

◦RNG supply operating facilities – This includes the generation, extraction, and sale of RNG - plus associated RINs and LCFSs from landfills.

For the three and nine months ended September 30, 2023 and 2022, the Company has accounted for its interests in Pine Bend, Reynolds and Noble Road under the equity method of accounting and the results of operations of Beacon, New River, Central Valley and Sunoma were consolidated in its condensed consolidated statement of operations. As of May 30, 2023, the Company deconsolidated Emerald and Sapphire. As a result, the Company consolidated Emerald and Sapphire for the period between January 1, 2023 and May 30, 2023 and recorded its ownership interests in Paragon which includes Emerald and Sapphire as equity method investment for the period between May 30, 2023 and September 30, 2023.

As of September 30, 2023, Central Valley, and Sapphire are not operational. Sunoma became operational in December 2021, Noble Road in January 2022, New River in April 2022 and Pine Bend in September 2022. Emerald began commercial operations in the third quarter of 2023.

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

◦Service and maintenance contracts for RNG/CNG fueling sites and a manufacturing division that builds Compact Fueling Systems and Defueling systems.

◦Third Party CNG Construction of Fueling Stations - design/build and serve as general contractor for typically Guarantee Maximum Price or fixed priced contracts for customers usually lasting less than one year.

◦RNG and CNG fuel dispensing stations for vehicle fleets - This includes both the dispensing and sale of brown gas and the environmental credit generation and monetization. The Company operates Fueling Stations that dispense gas for vehicles. This also includes the development and construction of these facilities.

•Renewable Power Portfolio. The Renewable Power portfolio segment generates renewable power through methane-rich landfills which is then sold to public utilities throughout the United States. The Renewable Power portfolio operates primarily in Southern California.

•Corporate. This segment consists of activities managed and maintained at the Company corporate level primarily including but not limited to:

◦Executive, accounting, finance, sales activities such as: payroll, stock compensation expense, travel and other related costs.

◦Insurance, professional fees (audit, tax, legal etc.).

The Company has determined that each of the four operating segments meets the characteristics of a reportable segment under U.S. GAAP. The Company's activities and assets that are not associated with the four reportable segments are summarized in the "Other" category below. These include corporate investment income, interest income and interest expense, income tax expense, and other non-allocated costs.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Revenues:
Renewable Power	$	13,708	$	49,737	$	43,543	$	70,937
RNG Fuel	29,551		22,788		61,395		61,971
Fuel Station Services	40,326		39,333		99,056		91,325
Intersegment	(3,021)		(3,150)		(10,967)		(8,172)
Equity Method Investment(s)	(9,463)		(42,158)		(23,927)		(47,247)
	$	71,101	$	66,550	$	169,100	$	168,814

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Interest and Financing Expense, Net:
Renewable Power	$	(2)	$	(1,440)	$	(260)	$	(3,559)
RNG Fuel	(3,243)		(189)		(4,616)		(240)
Fuel Station Services	27		(14)		120		(28)
Corporate	333		853		274		(3,385)
	$	(2,885)	$	(790)	$	(4,482)	$	(7,212)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Depreciation, Amortization, and Accretion:
Renewable Power	$	1,488	$	1,176	$	4,389	$	4,283
RNG Fuel	2,492		2,461		6,808		6,379
Fuel Station Services	917		411		2,555		616
Other(1)	9		31		36		95
Equity Method Investment(s)	(1,167)		(699)		(2,854)		(1,272)
	$	3,739	$	3,380	$	10,934	$	10,101

(1)Other includes amortization of intangible assets and depreciation expense not allocated to any segment.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Net income (loss)
Renewable Power	$	983	$	3,483	$	10,584	$	1,314
RNG Fuel	10,821		5,669		8,044		21,775
Fuel Station Services	5,530		11,624		7,429		12,574
Corporate	(18,833)		(19,101)		79,441		(38,761)
Equity Method Investment(s)	1,726		3,694		1,433		3,658
	$	227	$	5,369	$	106,931	$	560

	Nine Months Ended September 30,
	2023		2022
Cash paid for Purchases of Property, Plant, and Equipment:
Renewable Power	$	—	$	1,800
Fuel Station Services	16,860		7,038
RNG Fuel	75,390		76,496
	$	92,250	$	85,334

	September 30, 2023		December 31, 2022
Total Assets:
Renewable Power	$	39,503	$	43,468
RNG Fuel	290,247		347,750
Fuel Station Services	131,838		119,669
Corporate	29,401		82,204
Equity Method Investment(s)	199,466		51,765
	$	690,455	$	644,856

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

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Variable Interest Entities

9 Months Ended

Sep. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Variable Interest Entities

Variable Interest EntitiesWe determine whether we are the primary beneficiary of a VIE upon our initial involvement with the VIE and we reassess whether we are the primary beneficiary of a VIE on an ongoing basis. Our determination of whether we are the primary beneficiary of a VIE is based upon the facts and circumstances for each VIE and requires judgment. Our considerations in determining the VIE's most significant activities and whether we have power to direct those activities

include, but are not limited to, the VIE's purpose and design and the risks passed through to investors, the voting interests of the VIE, management, service and/or other agreements of the VIE, involvement in the VIE's initial design, and the existence of explicit or implicit financial guarantees. If we are the party with the power over the most significant activities, we meet the "power" criteria of the primary beneficiary. If we do not have the power over the most significant activities or we determine that all significant decisions require consent of a third party, we do not meet the "power" criteria of the primary beneficiary.

We assess our variable interests in a VIE both individually and in aggregate to determine whether we have an obligation to absorb losses of or a right to receive benefits from the VIE that could potentially be significant to the VIE. The determination of whether our variable interest is significant to the VIE requires judgment. In determining the significance of our variable interest, we consider the terms, characteristics and size of the variable interests, the design and characteristics of the VIE, our involvement in the VIE, and our market-making activities related to the variable interests.

As of September 30, 2023, the Company held equity interests in seven VIEs — Sunoma, GREP, Emerald, Sapphire, Paragon, SJI Joint Venture (RNG Atlantic and RNG Burlington) and Central Valley. On May 30, 2023, the Company together with a third-party environmental solutions company formed Paragon. The Company owns 50% of ownership interest in Paragon. Concurrent with the formation of Paragon, the Company contributed its 50% ownership interests in Emerald and Sapphire to Paragon.

Upon the execution of the above the transaction, the Company reassessed its equity interests in Emerald and Sapphire under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in Paragon under ASC 810 because the governance of the joint venture is driven by an independent board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of Paragon.

Based on the above analysis, the Company determined that it should account for its ownership interests in Paragon under the equity method of accounting pursuant to ASC 323, Investments Equity Method and Joint Ventures, prospectively, as the Company has the ability to exercise significant influence, but not control over the joint venture company.

Prior to May 30, 2023, the Company consolidated these two entities in accordance with the variable interest entity model guidance under ASC 810, Consolidation.

On September 14, 2023, OPAL L2G, a wholly-owned indirect subsidiary of the Company, entered into the Agreement with SJI LRNG, a wholly-owned indirect subsidiary of SJI, establishing the terms and conditions of governance and operation of the SJI Joint Venture. The purpose of the SJI Joint Venture, which is owned 50/50 by OPAL L2G and SJI LRNG, is to develop, construct, own and operate Facilities to produce RNG using biogas generated by certain landfills.

Upon the execution of the above transaction, the Company reassessed its equity interests in the SJI Joint Venture under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in SJI Joint Venture under ASC 810 because the governance of the joint venture is driven by a board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of SJI Joint Venture. As of September 30, 2023, there have been no material contribution made by the Company in the SJI Joint Venture.

As of September 30, 2023, GREP and Paragon were presented as equity method investments and the remaining two VIEs Sunoma and Central Valley are consolidated by the Company.

At December 31, 2022, GREP has been presented as an equity method investment and the remaining four VIEs Sunoma, Emerald, Sapphire, and Central Valley are consolidated by the Company.

In 2020, the Company acquired a variable interest in Sunoma in a joint venture with a third-party who does not have any equity at risk but participates in proportionate share of income or losses, which may be significant. Additionally, the assets in Sunoma are collateralized under the Sunoma loan, the proceeds of which are used for partial financing of the construction of the Sunoma facility. Therefore, the significant assets and liabilities of Sunoma are parenthesized in the condensed consolidated balance sheets as of September 30, 2023 and December 31, 2022.

The Company determined that each of these entities are VIEs and in its capacity as a managing member except for Emerald and Sapphire, the Company is the primary beneficiary. The Company is deemed as a primary beneficiary based on two conditions:

•The Company, as a managing member, has the power to order the activities that significantly impact the economic performance of the two entities including establishment of strategic, operating, and capital decisions for each of these entities; and

•The Company has the obligation to absorb the potential losses for the right to receive potential benefits, which could be significant to the VIE;

As a primary beneficiary, the Company consolidates these entities in accordance with the variable interest entity model guidance under ASC 810, Consolidation.

Our variable interests in each of our VIEs arise primarily from our ownership of membership interests, construction commitments, our provision of operating and maintenance services, and our provision of environmental credit processing services to VIEs.

The following table summarizes the major condensed consolidated balance sheet items for consolidated VIEs as of September 30, 2023 and December 31, 2022. The information below 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 amount of assets that can only be used to settle obligations of the VIEs are parenthesized in the condensed consolidated balance sheets and are included in the asset totals listed in the table below.

	As of September 30, 2023		As of December 31, 2022
Assets
Current assets:
Cash and cash equivalents	$	1,302	$	12,506
Accounts receivable, net	79		966
Restricted cash - current	1,232		6,971
Environmental credits held for sale	29		—
Prepaid expenses and other current assets	193		415
Total current assets	2,835		20,858
Property, plant and equipment, net	26,684		73,140
Restricted cash, non-current	2,843		2,923
Total assets	$	32,362	$	96,921
Liabilities and equity
Current liabilities:
Accounts payable	$	603	$	4,896
Accounts payable, related party	1,035		433
Accrued capital expenses	—		7,821
Accrued expenses	602		646
Sunoma Loan- current portion	1,739		380
Total current liabilities	3,979		14,176
Sunoma loan, net of debt issuance costs	20,402		21,712
Total liabilities	24,381		35,888
Equity
Stockholders' equity	7,097		34,588
Non-redeemable non-controlling interests	884		26,445
Total equity	7,981		61,033
Total Liabilities and Equity	$	32,362	$	96,921

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Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Deficit

9 Months Ended

Sep. 30, 2023

Equity [Abstract]

Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Deficit

Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Deficit

Common stock

As of September 30, 2023, there are (i) 29,332,333 shares of Class A common stock issued and outstanding, (ii) 144,399,037 shares of New OPAL Class D common stock issued and outstanding, (iii) no shares of Class B common stock, par value $0.0001 per share, 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) and (iv) no shares of Class C common stock, par value $0.0001 per share, (“ Class C common stock”) issued and outstanding (shares of Class D common stock do not have any economic value except voting rights as described below)

During the first quarter of 2023, Meteora exercised the put option pursuant to the terms of the Forward Purchase Contract. The Company repurchased 1,635,783 shares at a price of $10.02 per share. The Company recorded $11,614 representing the fair value of the treasury stock as part of stockholders' deficit and $4,777 as an offset to the derivative financial liability, current on its condensed consolidated balance sheet as of September 30, 2023.

In March 2023, the Company issued 49,633 shares to certain warrant holders as consideration for their prior agreement to tender all warrants held by the warrant holders in the Company's voluntary exchange offer which closed on December

22, 2022. The Company recorded $338 representing the fair value of the shares issued based on the closing price on March 30, 2023 as part of Other income (expense), net.

Redeemable preferred non-controlling interests

On November 29, 2021, as part of an Exchange Agreement, the Company issued 300,000 Series A-1 preferred units to Hillman in return for Hillman’s non-controlling interest in four RNG project subsidiaries.

On November 29, 2021, NextEra subscribed for up to 1,000,000 Series A preferred units, which are 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.

Upon completion of the Business Combination, the Company assumed Series A-1 preferred units and Series A preferred units which were issued and outstanding by OPAL Fuels. The Company recorded the Series A-1 preferred units and Series A preferred units as Redeemable preferred non-controlling interests. The Company has elected to adjust the carrying value of the preferred units to the redemption value at the end of each reporting period by immediately amortizing the issuance costs in the first reporting period after issuance of the preferred units.

During the third quarter of 2023, the Company repaid all outstanding paid-in-kind preferred dividends.

The following table summarizes the changes in the redeemable preferred non-controlling interests which represent Series A and Series A-1 preferred units outstanding at OPAL Fuels level from December 31, 2022 to September 30, 2023:

	Series A-1 preferred units			Series A preferred units
	Units	Amount		Units	Amount		Total
Balance, December 31, 2022	300,000	$	32,736	1,000,000	$	105,406	$	138,142
Series A units issued by OPAL Fuels	—	—		—	—		—
Paid-in-kind dividends attributable to OPAL Fuels	—	320		—	1,032		1,352
Paid-in kind dividends attributable to Class A common stockholders	—	1,666		—	5,376		7,042
Repayment of paid-in-kind preferred dividends	—	(4,722)		—	$	(11,814)	(16,536)
Balance, September 30, 2023	300,000	$	30,000	1,000,000	$	100,000	$	130,000

Terms of Redeemable Preferred Units

The Series A and Series A-1 preferred units (together the “Preferred Units”) are subject to substantially the same terms and features which are listed below:

Voting: The Series A-1 preferred units to Hillman do not have any voting rights. The Series A preferred units issued to NextEra have limited rights to prevent the Company 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 dispositions of assets and (iv) major acquisitions of assets outside of the Company’s primary business.

Dividends: The 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 is allowed to elect to issue additional Preferred Units ( paid-in-kind) in lieu of cash for the first eight dividend payment dates. The Company elected to pay the dividends to be paid-in-kind for all periods presented. The annual dividend rate increases to 12% if certain events of defaults occur. Additionally, the dividend rate increases by 2% for each unrelated uncured event of default up to a maximum of 20%.

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

Redemption: Any time after issuance, the Company may redeem the Redeemable preferred units for a price equal to original issue price of $100 per unit plus any accrued and unpaid dividends. Holders of the Preferred Units may redeem for an amount equal to original issue price of $100 per unit plus any accrued and unpaid dividends (i) upon the occurrence of certain change in control event (ii) at the end of four years from the date of issuance, except that the Preferred Units issued to Hillman can only be redeemed 30 days after the fourth year anniversary of the first issuance of Preferred Units to NextEra. The maturity date is determined to be the date at which the Holder’s redemption option becomes exercisable as this is the date on which both the Company and the Holder may redeem the Preferred Units. The maturity date may be as early as November 29, 2025 but shall not occur later than June 30, 2026.

Conversion: Holders may elect to convert Preferred Units into common units in the event that the Company fails to redeem the Preferred Units under an optional redemption. The annual dividend rate shall increase to 12% and will further increase to 14% after one year, and thereafter by 2% every 90 days up to a maximum of 20%. The Company must also redeem all NextEra Series A preferred units on which the redemption option has been exercised prior to redeeming any Hillman Series A-1 preferred units. If elected, the Holder may convert all or a portion of its Preferred Units into a number of common units equal to the number of Preferred Units, multiplied by$100, plus accrued and unpaid cash dividends, divided by the conversion price. The conversion price is equal to the value of the Company’s common units determined as follows, and reduced by (i) a 20% discount if conversion occurs during the first year of delayed redemption, (ii) a 25% discount during the 2nd year, and (iii) a 30% discount thereafter:

1. Using 20-day volume-weighted average price (“VWAP”) of the Company's common shares.

2. Otherwise the estimated proceeds to be received by the Holder of a common unit if the net assets of the Company were sold at fair market value and distributed.

Redeemable non-controlling interests

Upon consummation of the Business Combination, OPAL Fuels and its members caused the existing Limited Liability Company Agreement to be amended and restated. In connection therewith, all of the common units of OPAL Fuels issued and outstanding immediately prior to the Business Combination were re-classified into 144,399,037 Class B Units. Each Class B Unit is paired with a single non-economic share of Class D common stock issued by the Company. Each pair of Class B Unit and a single share of Class D common stock is exchangeable to either a single share of Class A common stock or a single share of Class C common stock at the holder's option. Upon an exchange for Class A common stock, the Company has the option to redeem shares for cash at their market value.

Redeemable non-controlling interests have been presented as mezzanine equity in the condensed consolidated statements of change in Redeemable non-controlling interests, Redeemable preferred non-controlling interests and stockholders' equity. At each balance sheet date, the Redeemable non-controlling interests are adjusted up to their redemption value if necessary, with an offset in Stockholders' equity. As of September 30, 2023, the Company recorded $1,158,937 to adjust the carrying value to their redemption value based on a five-day VWAP of $8.03 per share.

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Stock-based compensation

9 Months Ended

Sep. 30, 2023

Share-Based Payment Arrangement [Abstract]

Stock-based compensation

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

On March 31, 2023, the Company issued 196,961 stock options, 888,831 restricted stock units and 274,617 performance units to certain employees of the Company. The fair value of the stock options was determined to be $5.26 based on Black Scholes model based on the share price of $6.97, exercise price of $6.97, expiration of 10 years, annual risk free interest rate of 4.04% and volatility of 65%. Additionally, the Company issued 135,583 restricted stock units to the board of directors. The total fair value of the equity awards was $6,955.

A summary of the equity awards under the 2022 Plan for the nine months ended September 30, 2023 is as follows:

	Number of Units outstanding	Weighted Average Grant Date Fair Value		Aggregate Fair Value (in thousands)
Restricted Stock Units:
Unvested awards as of December 31, 2022	422,349	$	7.94
Granted	1,038,347	6.98
Vested in August 2023	(2,135)	6.97
Shares withheld for settlement of taxes	(1,046)
Forfeitures	(50,378)	7.49
Restricted Stock Units outstanding as of September 30, 2023	1,407,137	$	7.31	$	10,284
Stock Options:
Unvested awards as of December 31, 2022	—	—
Granted	196,961	$	5.26
Stock Options outstanding as of September 30, 2023	196,961	$	5.26	$	1,036
Performance Stock Units:
Unvested awards as of December 31, 2022	—
Granted	274,617	$	6.97
Vested in August 2023	(83)
Shares withheld for settlement of taxes	(31)
Forfeitures	(3,975)	$	6.97
Performance Stock Units outstanding as of September 30, 2023	270,528	$	6.97	$	1,553
Total unvested awards outstanding as of September 30, 2023	1,874,626	$	6.87	$	12,873

Stock-based compensation expense for all stock awards included in Selling, general and administrative expenses:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Stock-based compensation expense	$	1,899	$	160	$	4,747	$	320
	$	1,899	$	160	$	4,747	$	320

Stock-based compensation expense related to unvested awards yet to be recognized as of September 30, 2023 totaled $7,705 and is expected to be recognized, on a weighted average basis, over 2.3 years.

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Net (Loss) Income Per Share

9 Months Ended

Sep. 30, 2023

Earnings Per Share [Abstract]

Net (Loss) Income Per Share

Net (Loss) Income Per Share

The basic income per share of Class A common stock is computed by dividing the net (loss) income attributable to Class A common stockholders by the weighted average number of Class A common stock outstanding during the period. The basic income per share for the three and nine months ended September 30, 2023 does not include 1,635,783 shares in treasury, 763,908 shares issued and outstanding but are contingent on achieving earnout targets. In the first quarter of 2023, the put option was exercised and 197,258 shares of Class A common stock were cancelled.

The diluted income per share of Class A common stock for the three and nine months ended September 30, 2023 does not include Redeemable preferred non-controlling interests because the substantive contingency for conversion has not been met as of September 30, 2023. It does not include 144,399,037 OPAL Fuels Class B units representing Redeemable non-controlling interest as its impact is anti-dilutive. It does not include 763,908 Sponsor Earnout Awards and 10,000,000 OPAL Earnout Awards as their target share price and adjusted EBITDA contingencies have not been met as of September 30, 2023. The outstanding stock options issued under the 2022 Plan are not included as their impact is antidilutive. The outstanding performance units under the 2022 Plan are not included as the performance conditions have not been met as of September 30, 2023.

The Class D common stock does not participate in the earnings or losses of the Company and are therefore not participating securities. As such, separate presentation of basic and diluted earnings per share of Class D common stock under the two-class method has not been presented.

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

	Three Months Ended		Nine Months Ended
	September 30, 2023		September 30, 2023
Net (loss) income attributable to Class A common stockholders	(400)		$	15,945
Weighted average number of shares of Class A common stock - basic	26,978,969		27,110,953
Dilutive effect of stock options, restricted stock units, performance units, Convertible note payable, earnout shares, Redeemable preferred non-controlling interests, Redeemable non-controlling interests	—		572,902
Weighted average number of shares of Class A common stock - diluted	26,978,969		27,683,855
Net loss per share of Class A common stock
Basic	$	(0.01)	$	0.59
Diluted	$	(0.01)	$	0.58

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Income Taxes

9 Months Ended

Sep. 30, 2023

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes As a result of the Company’s up-C structure effective with the Business Combination, the Company expects to be a tax-paying entity. However, as the Company has historically been loss-making, any deferred tax assets created as a result of net operating losses and other deferred tax assets for the excess of tax basis in the Company's investment in Opal Fuels would be offset by a full valuation allowance. Prior to the Business Combination, OPAL Fuels was organized as a limited liability company, with the exception of one partially-owned subsidiary which filed income tax returns as a C-Corporation. The Company accounts for its income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to the differences between the financial statement carrying amount of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in earnings in the period that includes the enactment date. Judgment is required in determining the provisions for income and other taxes and related accruals, and deferred tax assets and liabilities. In the ordinary course of

business, there may be transactions and calculations where the ultimate tax outcome is uncertain. Additionally, the Company's various tax returns are subject to audit by various tax authorities. Although the Company believes that its estimates are reasonable, actual results could differ from these estimates.

For the three and nine months ended September 30, 2023, the Company recorded zero income tax expense. The effective tax rate for the three and nine months ended September 30, 2023 was 0%. The difference between the Company’s effective tax rate for the three and nine months ended September 30, 2023 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 did not record a tax provision for the three and nine months ended September 30, 2022 primarily due to OPAL Fuels' status as a pass-through entity for U.S. federal income tax purposes. 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.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2023

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Letters of Credit

As of September 30, 2023 and December 31, 2022, the Company was required to maintain five and nine standby letters of credit totaling $10,498 and $2,292, respectively, to support obligations of certain Company 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.

Purchase Options

The Company has two contracts with customers to provide CNG for periods of seven and ten years, respectively. The customers have an option to terminate the contracts and purchase the Company's CNG Fueling Station at the customers' sites for a fixed amount that declines annually.

In July 2015, the Company entered into a ten year Fuel Sales Agreement with a customer that included the construction of a CNG Fueling Station owned and managed by the Company on the customer's premises. At the end of the contract term, the customer has an option to purchase the CNG Fueling Station for a fixed amount. The cost of the CNG Fueling Station was recorded to Property, plant, and equipment and is being depreciated over the contract term.

On May 30, 2023, OPAL Intermediate Holdco 2 assigned to Paragon its rights and obligations under the OPAL Term Loan II. Additionally, the Company signed an equity commitment letter up to a maximum of $2,100, to Paragon relating to its share of equity contribution towards any cost over runs in connection with the construction and completion of Emerald project.

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.

In September 2021, an indirect subsidiary of the Company, MD Digester, LLC entered into a fixed-price Engineering, Procurement and Construction Contract (an “EPC Contract”) with VEC Partners, Inc. dba 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 entered into a nearly identical EPC Contract for the design and construction of a second facility, also in California’s Central Valley. CEI’s performance under both of the EPC Contracts is fully bonded by licensed sureties.

CEI has submitted a series of change order requests seeking to increase the EPC Contract Price by approximately $14 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 termination (for default) of one of CEI’s major equipment manufacturers. The Company disputes the vast majority of the change order requests. The Company, CEI and CEI’s surety are in active settlement discussions and have agreed to a temporary funding arrangement pending resolution of the disputed change

orders to keep the projects moving forward. No formal legal proceedings have been filed, and no discovery has been performed.

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Subsequent Events

9 Months Ended

Sep. 30, 2023

Subsequent Events [Abstract]

Subsequent Events

Subsequent Events

On October 5, 2023, Ms. Ann Anthony gave notice of her intention to resign as Chief Financial Officer ("CFO") of the Company to pursue another professional opportunity. Ms. Anthony’s departure date was at the time not yet determined. Ms. Anthony will, also resign from her positions as the Company’s Principal Financial Officer and Principal Accounting Officer. On October 10, 2023, the board of directors of the Company appointed Mr. Scott Contino as Interim Chief Financial Officer. Mr. Contino will assist Ms. Anthony during the transition and assume the CFO role on the date of Ms. Anthony’s departure. The Company has entered into an interim services agreement (the “Interim Services Agreement”) with Fortistar in accordance with the terms and conditions of the existing Administrative Services Agreement between the Company and Fortistar. Pursuant to the Interim Services Agreement, the Company will pay Fortistar a services fee as described below, which is substantially the same as the cash compensation that was paid to Ms. Anthony.

On October 19, 2023, Ms. Anthony signed a separation agreement with the Company, pursuant to which Ms. Anthony has agreed to serve in her current role until November 15, 2023. Certain equity incentive awards that were granted to Ms. Anthony, and that would have otherwise been forfeited due to her resignation, will vest on March 31, 2024 in accordance with the Separation Agreement. These equity awards consist of 33,328 restricted stock units and options to purchase 5,545 shares of Class A Common Stock at an exercise price of $6.97.

On October 20, 2023 (the “Effective Date”), a wholly-owned subsidiary of the Company entered into an Asset Purchase and Sale Agreement (for the purposes of this paragraph, the “Agreement”) with Washington Gas Light Company ("WGL"). The subsidiary is currently constructing a production facility (the “Facility”) at the Prince William County landfill located in Manassas, Virginia, on a parcel located on the landfill, to process landfill gas into RNG. The Agreement obligates the subsidiary to develop, plan and permit a gas pipeline extension and associated interconnection facilities (the “Project”) to deliver RNG from the Facility to an interconnection point on WGL’s pipeline. Per the terms and conditions of the Agreement, WGL will purchase the Project from the subsidiary after the final completion of same at a purchase price of $25 million. The closing is contingent upon approval of the Agreement by the Virginia State Corporation Commission, as well as the satisfaction of customary closing conditions, and the outside closing date is on or prior to the 12-month anniversary of the Effective Date.

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Insider Trading Arrangements	3 Months Ended
	Sep. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

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Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Basis of Presentation and Principles of Consolidation

Basis of Presentation and Principles of Consolidation

These unaudited condensed consolidated financial statements are prepared in accordance with generally accepted accounting principles in the United States ("U.S. GAAP") and include the accounts of the Company and all other entities in which the Company has a controlling financial interest: OPAL Renewable Power LLC (formerly Fortistar Methane 3 LLC (“FM3”) and Fortistar Methane 4 LLC), Beacon RNG LLC (“Beacon”) Sunoma Holdings, LLC (“Sunoma”), New River LLC (“New River”), Reynolds RNG LLC (“Reynolds”), Central Valley LLC (“Central Valley”), Prince William RNG LLC (“Prince William”), Cottonwood RNG LLC, Polk County RNG LLC (“Polk County”), OPAL Contracting LLC (formerly Fortistar Contracting LLC), OPAL RNG LLC (formerly Fortistar RNG LLC), and OPAL Fuel station services LLC (“Fuel Station Services”). The Company’s unaudited condensed consolidated financial statements include the assets and liabilities of these subsidiaries. All intercompany transactions and balances have been eliminated in consolidation. The non-controlling interest attributable to the Company's variable interest entities ("VIE") is presented as a separate component from the Stockholders' deficit in the condensed consolidated balance sheets. It is presented 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 the Stockholders' deficit.

The accompanying unaudited condensed consolidated financial statements reflect the activities of the Company, its subsidiaries, and its equity method investments for the three and nine months ended September 30, 2023 and 2022. Investments in unconsolidated entities in which the Company has influence over the operating or financial decisions are accounted for under the equity method. On May 30, 2023, the Company together with a third-party environmental solutions company formed Paragon LLC ("Paragon"), a new joint venture holding company. The Company owns 50% of the ownership interest in Paragon. Concurrent to the formation of Paragon, the Company contributed its 50% ownership interests in Emerald and Sapphire to Paragon. Upon the execution of the above transaction, the Company reassessed its equity interests in Emerald RNG LLC ("Emerald") and Sapphire RNG LLC ("Sapphire") under ASC 810, Consolidation and determined that the Company did not have a controlling financial interest in Paragon under ASC 810 because the governance of Paragon is driven by a board jointly controlled equally by the joint venture partner and the Company and there are substantive participating rights held by the joint venture partner in the significant activities of Paragon. As a result of the reassessment, the Company deconsolidated these two entities effective May 30, 2023. Prior to May 30, 2023, the Company consolidated these two entities in accordance with the variable interest entity model guidance under ASC 810, Consolidation.

On September 14, 2023, OPAL Land2Gas LLC (“OPAL L2G”), a wholly-owned indirect subsidiary of OPAL Fuels Inc. (the “Company”), entered into a Limited Liability Company Agreement (for purposes of this paragraph, the “Agreement”) with SJI Landfill RNG LLC (“SJI LRNG”), a wholly-owned indirect subsidiary of South Jersey Industries (“SJI”), establishing the terms and conditions of governance and operation of Land2Gas LLC (the “ SJI Joint Venture”). The purpose of the Joint Venture, which is owned 50/50 by OPAL L2G and SJI LRNG, is to develop, construct, own and operate facilities (“Facilities”) to produce RNG using biogas generated by certain landfills. The Agreement governs the terms and conditions of capital contributions to be made by the SJI Joint Venture members to fund the development, construction and operations of the Facilities. The Agreement requires members of the SJI Joint Venture to contribute their respective share (50% each) of such capital requirements. The Agreement initially contemplates two RNG projects (RNG Atlantic and RNG Burlington) in New Jersey with each RNG project represented as a separate series of membership interests, also owned 50-50 by the members. Further, the Agreement provides for the SJI Joint Venture to enter into a Management Services Agreement (“MSA”), Operations and Maintenance Agreement (“O&M Agreement”), and dispensing agreement with certain wholly-owned, indirect subsidiaries of the Company. The MSA establishes the terms and conditions for the day-to-day administration of the projects, including responsibility for managing the development and overseeing the construction of the Facilities. The O&M Agreement establishes the terms and conditions for operating and maintaining the Facilities once construction is completed. The Dispensing Agreement provides for the acquisition, marketing and sale of the Environmental Attributes associated with RNG produced by the Facilities.

Upon the execution of the above transaction, the Company reassessed its equity interests in the SJI Joint Venture under ASC 810, Consolidation and determined that the Company does not have a controlling financial interest in SJI Joint Venture under ASC 810 because the governance of the joint venture is driven by a board jointly controlled by the joint venture partner and OPAL equally and there are substantive participating rights held by the joint venture partner in the significant activities of SJI Joint Venture. As of September 30, 2023, there have been no material contributions made by the Company in the SJI Joint Venture.

As of September 30, 2023, the Company accounted for its ownership interests in Pine Bend RNG LLC ("Pine Bend"), Noble Road RNG LLC ("Noble Road"), Emerald, Sapphire, Paragon, SJI Joint Venture (RNG Atlantic and RNG Burlington) and GREP BTB Holdings LLC ("GREP") under the equity method.

As of December 31, 2022, the Company accounted for its ownership interests in Pine Bend, Noble Road and GREP under the equity method. Please see Note 3. Investment in Other Entities, for additional information.

The accompanying unaudited condensed financial statements have been prepared in accordance with the instructions to Form 10-Q and Article 10 of Regulation S-X of the Securities and Exchange Commission ("SEC"). Certain information or footnote disclosures normally included in financial statements prepared in accordance with U.S. GAAP have been condensed or omitted, pursuant to the rules and regulations of the SEC for interim financial reporting. Accordingly, it does not include all the information and footnotes necessary for a complete presentation of financial position, results of operations, or cash flows. The information herein should be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company's Annual Report. In the opinion of management, the accompanying unaudited condensed financial statements include all adjustments, consisting of a normal recurring nature, which are necessary for a fair statement of the financial position, operating results, and cash flows for the periods presented.

Use of Estimates

Use of Estimates

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

The significant estimates and assumptions of the Company include the residual value of the useful lives of our property, plant and equipment, the fair value of stock-based compensation, asset retirement obligations, the estimated losses on our trade receivables, percentage completion for revenue recognition, incremental borrowing rate for calculating the right-of-use assets and lease liabilities, the impairment assessment of goodwill, the fair value of deconsolidated VIEs 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.

Accounting Pronouncements Adopted and Accounting Pronouncements Not Yet Adopted

Accounting Pronouncements Adopted

In June 2016, the Financial Standards Accounting Board ("FASB") issued ASU 2016-13, Financial Instruments — Credit Losses ("ASC 326"), with the objective of providing information about the credit risk inherent in an entity’s financial statements as well as to explain management’s estimate of expected credit losses and the changes in the allowance for such losses. The accounting standard amends the current financial instrument impairment model by requiring entities to use a forward-looking approach based on expected losses to estimate credit losses on certain types of financial instruments, including trade receivables. Under the new guidance, an entity recognizes as an allowance, its estimate of lifetime expected credit losses, which will result in more timely recognition of such losses. The Company adopted the accounting standard using the prospective transition approach as of January 1, 2023. The cumulative effect upon adoption was not material to our condensed consolidated financial statements.

The adoption of ASC 326 primarily impacted our trade receivables and the Note receivable - variable fee component recorded on our condensed consolidated balance sheet as of September 30, 2023. Upon adoption of ASC 326, the Company assessed collectability by reviewing accounts receivable on a collective basis where similar characteristics exist and on an individual basis when we identify specific customers with known disputes or collectability issues. In determining the amount of the allowance for credit losses, the Company considered historical collectability based on past due status and made judgments about the creditworthiness of customers based on ongoing credit evaluations. The Company also considered customer-specific information, current market conditions and reasonable and supportable forecasts of future economic conditions to inform adjustments to historical loss data. The carrying value of the Note receivable - variable fee component on the condensed consolidated balance sheet as of September 30, 2023 is based on a discounted expected cash flows model which is adjusted on a quarterly basis. Therefore, the Company determined that the credit risk component is included in the carrying value at each reporting period. The adoption of ASC 326 did not have any material impact on our condensed consolidated financial statements.

Accounting Pronouncements Not Yet Adopted

In March 2023, the FASB issued Accounting Standards Update No. 2023-01, Leases (Topic 842) (the "Update"). The Update requires the entities to classify and account for a leasing arrangement between entities under common control on the same basis as an arrangement with an unrelated party. The Update also requires that leasehold improvements associated with common control leases be amortized by the lessee over the useful life of the leasehold improvements to the common control group (regardless of the lease term) as long as the lessee controls the use of the underlying asset and accounts for the underlying asset as a transfer between entities under common control through an adjustment to equity if and when the lessee no longer controls the use of the underlying asset. The amendments in this Update are effective for fiscal years beginning after December 15, 2023 including interim fiscal periods within those fiscal years. The Company is currently evaluating the impact of the adoption of this Update on its condensed consolidated financial statements.

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. The Company is currently evaluating the impact of the adoption of ASU 2023-05 on its condensed consolidated financial statements.

Short term investments

Short term investments

The Company considers highly liquid investments such as time deposits and certificates of deposit with an original maturity greater than three months at the time of purchase to be short term investments. The short term investments of $18,028 and $64,976 as of September 30, 2023 and December 31, 2022, respectively, consist of commercial paper invested in money market accounts with maturities ranging between 1 and 12 months as of the reporting date. The amounts in these accounts are liquid and available for general use.

Our short term investments are generally invested in commercial paper issued by highly credit worthy counter parties and government-backed treasury bills. Investments are generally not FDIC insured and we take counterparty risk on these investments.

Earnout liabilities

Earnout liabilities

In connection with the business combination ("Business Combination") completed in July 2022 and pursuant to a sponsor letter agreement, ArcLight CTC Holdings II, L.P. (the "Sponsor") 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. OPAL Fuels equity holders are eligible to receive an aggregate of 10,000,000 shares of Class B and Class D common stock upon the Company achieving each earn-out event during the earn-out period. The earnout awards (the "Earnout Awards") were recognized at fair value on the closing date and classified as a liability

which is remeasured at each balance sheet date and any change in fair value is recognized in the Company's condensed consolidated statement of operations as part of change in fair value of derivative instruments, net.

Redeemable non-controlling interests

Redeemable non-controlling interests

Redeemable non-controlling interests represent the portion of OPAL Fuels that the Company controls and consolidates but does not own. The Redeemable non-controlling interest was created as a result of the Business Combination and represents 144,399,037 Class D 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 statement of operations.

At each balance sheet date, the mezzanine equity classified as Redeemable non-controlling interests is adjusted up to its maximum redemption value if necessary, with an offset in Stockholders' equity.

Net Income Per Share

Net Income Per Share

The Company's basic earnings per share of Class A common stock is computed based on the average number of outstanding shares of Class A common stock for the period.

The Company's diluted earnings per share includes effects of the Company's outstanding equity awards under the 2022 Plan (as defined elsewhere in these financial statements), Redeemable non-controlling interests (OPAL Fuels Class B units), redeemable preferred non-controlling interests, Sponsor Earnout Awards and OPAL Earnout Awards.

Asset Retirement Obligation

Asset Retirement Obligation

The Company accounts for asset retirement obligations in accordance with FASB ASC 410, Asset Retirement and Environmental Obligations, which requires entities to record 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 fair value of the estimated asset retirement obligations is recorded as a long-term liability, with a corresponding increase in the carrying amount of the related asset. The discounted asset retirement costs capitalized amounts are accreted over the life of the sublease or site lease agreement. Asset retirement obligations are deemed Level 3 fair value measurements as the inputs used to measure the fair value are unobservable. The Company estimates the fair value of asset retirement obligations by calculating the estimated present value of the cost to retire the asset. This estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental, and political environments. In addition, the Company determines the Level 3 fair value measurements based on historical information and current market conditions.

Revenue Recognition

Revenue Recognition

The Company’s revenue arrangements generally consist of a single performance obligation to transfer goods or services. Revenue from the sale of RNG, CNG and electricity is recognized by applying the “right to invoice” practical expedient within the accounting guidance for Revenue from Contracts with Customers that allows for the recognition of revenue from performance obligations in the amount of consideration to which there is a right to invoice the customer and when the amount for which there is a right to invoice corresponds directly to the value transferred to the customer. For some public CNG Fueling Stations where there is no contract with the customer, the Company recognizes revenue at the point in time that the customer takes control of the fuel.

The Company also performs maintenance services throughout the country. Maintenance consists of monitoring equipment and replacing parts as necessary to ensure optimum performance. Revenue from service agreements is recognized over time as services are provided. Capacity payments fluctuate based on peak times of the year and revenues from capacity payments are recognized monthly as earned.

The Company has agreements with two natural gas producers ("Producers") to transport Producers' natural gas using the Company's RNG gathering system. The performance obligation is the delivery of Producers' natural gas to an agreed delivery point on an interstate gas pipeline. The quantity of natural gas transported for the Producers is measured at a certain specified meter. The price is fixed at contracted rates and the Producers pay approximately 30 days after month-end. As such, transportation sales are recognized over time, using the output method to measure progress.

The Company provides credit monetization services to customers that own renewable gas generation facilities. The Company recognizes revenue from these services as the credits are minted on behalf of the customer. The Company receives non-cash consideration in the form of Renewable Identification Numbers ("RINs") or LCFSs for providing these services and recognizes the RINs or LCFSs received as a current asset based on their estimated fair value at contract inception. When the Company receives RINs or LCFSs as payment for providing credit monetization services, it records the non-cash consideration in environmental credits held for sale within the unaudited condensed consolidated balance sheet based on the fair value of RINs or LCFSs at contract commencement.

On November 29, 2021, the Company entered into a purchase and sale agreement with NextEra, a related party for the Environmental Attributes generated by the RNG Fuels business. Under this agreement, the Company plans to sell a minimum of 90% of the Environmental Attributes generated and will receive net proceeds based on the agreed upon price

less a specified discount. A specified volume of Environmental Attributes sold per quarter will incur a fee per Environmental Attribute in addition to the specified discount. The agreement was effective beginning January 1, 2022. For the three months ended September 30, 2023 and 2022, the Company earned net revenues after discount and fees of $25,724 and $19,336, respectively. These amounts were recorded as part of Revenues - RNG fuel and Fuel Station Services. For the nine months ended September 30, 2023 and 2022, the Company earned net revenues after discount and fees of $43,784 and $49,024, respectively.

During third and fourth quarter of 2022, two of the wholly-owned subsidiaries from our Renewable Power portfolio entered into a purchase and sale agreement with an environmental attribute marketing firm to sell environmental attributes associated with renewable bio methane ("ISCC Carbon Credits") and purchase brown gas back at contracted fixed prices per million British thermal units ("MMbtu"). One of these contracts has a term of 3 years from the date of certification of the facility with an auto-renewal option. The other contract was terminated in August 2023. During the third quarter of 2023, two additional Renewable Power facilities entered into purchase and sale agreements with 3 year terms and similar terms and conditions as the previous contracts. These two facilities are expected to receive certification in the fourth quarter of 2023. These two facilities are expected to receive certification in the fourth quarter of 2023. For the three and nine months ended September 30, 2023, the Company earned net revenues of $3,732 and $13,425, respectively under this contract which were recorded as part of Revenues - Renewable Power in the unaudited condensed consolidated statement of operations. For the three and nine months ended September 30, 2022, the Company earned net revenues of $842 and recorded as part of Revenues - Renewable Power in the condensed consolidated statement of operations.

Sales of Environmental Attributes such as RINs, renewable energy credits ("RECs"), and LCFS are generally recorded as revenue when the certificates related to them are delivered to a buyer. However, the Company may recognize revenue from the sale of such Environmental Attributes at the time of the related renewable power sales when the contract provides that title to the Environmental Attributes transfers at the time of production, the Company's price to the buyer is fixed, and collection of the sales proceeds is certain.

Management operating fees are earned for the operation, maintenance, and repair of the gas collection system of a landfill site. Revenue is calculated on the volume of per MMBtu of LFG collected and the megawatt hours ("MWhs") produced at that site. This revenue is recognized when LFG is collected and renewable power is delivered.

The Company has various fixed price contracts for the construction of Fueling Stations for customers. Revenues from these contracts, including change orders, are recognized over time, with progress measured by the percentage of costs incurred to date compared to estimated total costs for each contract. This method is used as management considers costs incurred to be the best available measure of progress on these contracts. Costs capitalized to fulfill certain contracts were not material in any of the periods presented.

The Company owns Fueling Stations for use by customers under fuel sale agreements. The Company bills these customers at an agreed upon price for each gallon sold and recognizes revenue based on the amounts invoiced in accordance with the "right to invoice" practical expedient. For some public stations where there is no contract with the customer, the Company recognizes revenue at the point-in-time that the customer takes control of the fuel.

The Company from time-to-time enters into fuel purchase agreements with customers whereby 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. In accordance with the standards of ASC 840, Leases, the Company has concluded that these agreements meet the criteria for a lease and are classified as operating leases. Typically, these agreements do not require any minimum consumption amounts and, therefore, no minimum payments. Upon adoption of ASC 842, the Company adopted the practical expedient not to reassess the classification. For additional information on lease revenues earned, please see Note 8. Leases.

Income Taxes

Income Taxes

As a result of the Business Combination, the Company is the sole managing member of OPAL Fuels. OPAL Fuels is a limited liability company that is treated as a partnership for U.S. federal income tax purposes and for most applicable state and local income taxes. Any taxable income or loss generated by OPAL Fuels is passed through to and included in the taxable income or loss of its members, including the Company, on a pro-rata basis, subject to applicable tax regulations.

The Company accounts for income taxes in accordance with ASC Topic 740, Accounting for Income Taxes (“ASC Topic 740”), which requires the recognition of tax benefits or expenses on temporary differences between the financial reporting and tax bases of its assets and liabilities by applying the enacted tax rates in effect for the year in which the differences are expected to reverse. Such net tax effects on temporary differences are reflected on the Company’s unaudited condensed consolidated balance sheets as deferred tax assets and liabilities. Deferred tax assets are reduced by a valuation allowance when the Company believes that it is more-likely-than-not that some portion or all of the deferred tax assets will not be realized. The Company calculates the interim tax provision in accordance with the provisions of ASC Subtopic 740-270, Income Taxes; Interim Reporting. For interim periods, the Company estimates the annual effective income tax rate and applies the estimated rate to the year-to-date income or loss before income taxes.

As a result of the Company’s up-C structure effective with the Business Combination, the Company expects to be a tax-paying entity. However, as the Company has historically been loss-making, any deferred tax assets created as a result of net operating losses and other deferred tax assets for the excess of tax basis in the Company's investment in Opal Fuels would be offset by a full valuation allowance. Prior to the Business Combination, OPAL Fuels was organized as a limited liability company, with the exception of one partially-owned subsidiary which filed income tax returns as a C-Corporation. The Company accounts for its income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to the differences between the financial statement carrying amount of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in earnings in the period that includes the enactment date. Judgment is required in determining the provisions for income and other taxes and related accruals, and deferred tax assets and liabilities. In the ordinary course of business, there may be transactions and calculations where the ultimate tax outcome is uncertain. Additionally, the Company's various tax returns are subject to audit by various tax authorities. Although the Company believes that its estimates are reasonable, actual results could differ from these estimates.

Concentration of Credit Risk

Financial instruments that potentially subject the Company to concentrations of credit risk consist principally of cash and cash equivalents, and trade receivables. The Company places its cash in high credit quality financial institutions located in the United States of America. The Company performs ongoing credit evaluations of its customers.

Equity Method Investments

The Company uses the equity method to account for investments in affiliates that it does not control, but in which it has the ability to exercise significant influence over operating and financial policies. The Company's investments in these nonconsolidated affiliates are reflected in the Company's condensed consolidated balance sheets under the equity method, and the Company's proportionate net (loss) income, if any, is included in the Company's unaudited condensed consolidated statements of operations as (loss) income from equity method investments.

Leases

Leases

The following are the types of contracts that fall under ASC 842:

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. These are considered to be operating leases with variable consideration. As per ASC 842, the revenue is recognized in the period earned.

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. The Company elected not to reassess the lease classification due to change in criteria under ASC 842 for these two PPAs. There were no amendments to these two contracts after the Adoption Date.

Included in Fuel Station Service revenues are $917 and $2,119 related to the lease portion of the FPAs for the three and nine months ended September 30, 2023, respectively. This includes $856 and $1,906 related to the lease portion of the FPAs for the three and nine months ended September 30, 2022, respectively.

Included in Renewable Power revenues are $223 and $818 related to the lease element of the PPAs for the three and nine months ended September 30, 2023, respectively. Included in Renewable Power revenues are $384 and $1,014 related to the lease element of the PPAs for the three and nine ended September 30, 2022, respectively.

Lessee Contracts

Ground/Site Leases

The Company through various indirectly owned subsidiaries holds site leases on landfills and dairy farms to build RNG generation facilities. Typically, the lease payments over the lease term are immaterial except for three of our RNG facilities including Beacon and two sites at our Central Valley project - MS Digester ("MS") and VS Digester ("VS").

– The lease at the Beacon facility is for 20 years at a monthly rent of $11.

– The lease term for MD and VS is for a period of 20 years from their commercial operation date at a quarterly rent of $125.

On July 5, 2023, the Company through one of its indirectly owned subsidiary entered into a site lease on a dairy farm to build a facility to collect, process and deliver feedstock to an RNG facility. The lease term is 20 years from its commercial operations date at a quarterly rent of $21,250 with a 5% escalator on the calendar quarter in which the fifth anniversary occurs and every fifth anniversary thereafter. The Company recorded $798 as right-of-use operating lease and corresponding lease liability on its condensed consolidated balance sheet as of September 30, 2023 using an incremental borrowing rate of 8.44%,

Additionally, the Company revised the commercial operation date for its leases for MD and VS by 10 months which changed the lease term for both the leases. The Company treated this as a lease modification and increased its right-of-use asset and corresponding lease liability by $280 on its condensed consolidated balance sheet as of September 30, 2023, using the incremental borrowing rate of 8.44%.

Office Lease

The Company entered into a lease for office and warehouse space that became effective upon the termination of the original lease term on January 31, 2018. The term of the lease renewal was 36 months and contained an option to renew for an additional 24 months. In September 2020, the Company exercised this option. In March 2022, the Company entered into an amendment to the lease which extended the lease term till January 2026. The rent for the lease is $26 per month with a built in escalation to $27 from February 1, 2022 to February 1, 2023, $43 from February 1, 2023 - February 1, 2024, $45 from February 1 2024 - February 1, 2025 and $46 for the remaining lease term. The Company accounted for the change in the lease term as a lease modification and reassessed the right-of-use assets and corresponding lease liabilities as of March 31, 2022.

The Company currently shares office space with Fortistar and reimburses Fortistar on a monthly basis at a predetermined rate. The Company determined that this is not a lease under ASC 842 as there is no identifiable asset and the Company does not have the right to control the use of the office space.

The Company determined that the three site leases and the one office lease are operating leases.

Under ASC 842, leases are classified as either finance or operating arrangements, with such classification affecting the pattern and classification of expense recognition in an entity's income statement. For operating leases, ASC 842 requires recognition in an entity’s income statement of a single lease expense, calculated so that the cost of the lease is allocated over the lease term, generally on a straight-line basis. Right-of-use assets represent a right to use the underlying asset for the lease term and the related lease liability represents an obligation to make lease payments pursuant to the contractual terms of the lease agreement.

Based on the above guidance, the lease expense for the site leases is included as part of Cost of sales - RNG Fuel in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022. The lease expense for the office lease is recorded as part of Selling, general and administrative expenses in its condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022.

Vehicle Leases

The Company leases approximately 65 vehicles in our FM3 and OPAL Fuel Station Services subsidiaries. The leases contain repurchase options at the end of the lease term and the sum total of the lease payments represents substantially the fair value of the asset.

Under ASC 842, the Company determined that the vehicle leases are finance leases. For finance leases, ASC 842 requires recognition of amortization of right-of-use asset as part of depreciation and amortization expense and the interest on the finance lease liability as interest expense in the income statement. The Company accordingly recognized its lease expense on the vehicle leases as part of Depreciation, amortization and accretion expense and interest and financing expense, net in the condensed statement of operations for the three and nine months ended September 30, 2023 and 2022.

Lease Disclosures Under ASC 842

The objective of the disclosure requirements under ASC 842 is to enable viewers of an entity’s financial statements to assess the amount, timing and uncertainty of cash flows arising from lease arrangements. In addition to the supplemental qualitative leasing disclosures included above, below are quantitative disclosures that are intended to meet the stated objective of ASC 842.

Leases

Leases

The following are the types of contracts that fall under ASC 842:

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. These are considered to be operating leases with variable consideration. As per ASC 842, the revenue is recognized in the period earned.

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. The Company elected not to reassess the lease classification due to change in criteria under ASC 842 for these two PPAs. There were no amendments to these two contracts after the Adoption Date.

Included in Fuel Station Service revenues are $917 and $2,119 related to the lease portion of the FPAs for the three and nine months ended September 30, 2023, respectively. This includes $856 and $1,906 related to the lease portion of the FPAs for the three and nine months ended September 30, 2022, respectively.

Included in Renewable Power revenues are $223 and $818 related to the lease element of the PPAs for the three and nine months ended September 30, 2023, respectively. Included in Renewable Power revenues are $384 and $1,014 related to the lease element of the PPAs for the three and nine ended September 30, 2022, respectively.

Lessee Contracts

Ground/Site Leases

The Company through various indirectly owned subsidiaries holds site leases on landfills and dairy farms to build RNG generation facilities. Typically, the lease payments over the lease term are immaterial except for three of our RNG facilities including Beacon and two sites at our Central Valley project - MS Digester ("MS") and VS Digester ("VS").

– The lease at the Beacon facility is for 20 years at a monthly rent of $11.

– The lease term for MD and VS is for a period of 20 years from their commercial operation date at a quarterly rent of $125.

On July 5, 2023, the Company through one of its indirectly owned subsidiary entered into a site lease on a dairy farm to build a facility to collect, process and deliver feedstock to an RNG facility. The lease term is 20 years from its commercial operations date at a quarterly rent of $21,250 with a 5% escalator on the calendar quarter in which the fifth anniversary occurs and every fifth anniversary thereafter. The Company recorded $798 as right-of-use operating lease and corresponding lease liability on its condensed consolidated balance sheet as of September 30, 2023 using an incremental borrowing rate of 8.44%,

Additionally, the Company revised the commercial operation date for its leases for MD and VS by 10 months which changed the lease term for both the leases. The Company treated this as a lease modification and increased its right-of-use asset and corresponding lease liability by $280 on its condensed consolidated balance sheet as of September 30, 2023, using the incremental borrowing rate of 8.44%.

Office Lease

The Company entered into a lease for office and warehouse space that became effective upon the termination of the original lease term on January 31, 2018. The term of the lease renewal was 36 months and contained an option to renew for an additional 24 months. In September 2020, the Company exercised this option. In March 2022, the Company entered into an amendment to the lease which extended the lease term till January 2026. The rent for the lease is $26 per month with a built in escalation to $27 from February 1, 2022 to February 1, 2023, $43 from February 1, 2023 - February 1, 2024, $45 from February 1 2024 - February 1, 2025 and $46 for the remaining lease term. The Company accounted for the change in the lease term as a lease modification and reassessed the right-of-use assets and corresponding lease liabilities as of March 31, 2022.

The Company currently shares office space with Fortistar and reimburses Fortistar on a monthly basis at a predetermined rate. The Company determined that this is not a lease under ASC 842 as there is no identifiable asset and the Company does not have the right to control the use of the office space.

The Company determined that the three site leases and the one office lease are operating leases.

Under ASC 842, leases are classified as either finance or operating arrangements, with such classification affecting the pattern and classification of expense recognition in an entity's income statement. For operating leases, ASC 842 requires recognition in an entity’s income statement of a single lease expense, calculated so that the cost of the lease is allocated over the lease term, generally on a straight-line basis. Right-of-use assets represent a right to use the underlying asset for the lease term and the related lease liability represents an obligation to make lease payments pursuant to the contractual terms of the lease agreement.

Based on the above guidance, the lease expense for the site leases is included as part of Cost of sales - RNG Fuel in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022. The lease expense for the office lease is recorded as part of Selling, general and administrative expenses in its condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022.

Vehicle Leases

The Company leases approximately 65 vehicles in our FM3 and OPAL Fuel Station Services subsidiaries. The leases contain repurchase options at the end of the lease term and the sum total of the lease payments represents substantially the fair value of the asset.

Under ASC 842, the Company determined that the vehicle leases are finance leases. For finance leases, ASC 842 requires recognition of amortization of right-of-use asset as part of depreciation and amortization expense and the interest on the finance lease liability as interest expense in the income statement. The Company accordingly recognized its lease expense on the vehicle leases as part of Depreciation, amortization and accretion expense and interest and financing expense, net in the condensed statement of operations for the three and nine months ended September 30, 2023 and 2022.

Lease Disclosures Under ASC 842

The objective of the disclosure requirements under ASC 842 is to enable viewers of an entity’s financial statements to assess the amount, timing and uncertainty of cash flows arising from lease arrangements. In addition to the supplemental qualitative leasing disclosures included above, below are quantitative disclosures that are intended to meet the stated objective of ASC 842.

Interest Rate Swaps and Commodity Swap Contracts

Interest Rate Swaps

During August 2022, the Company entered into two interest rate swaps for the notional amount of $61,926 of the OPAL Term Loan II at a fixed interest rate of 2.47% to hedge the SOFR-based floating interest rate. On August 16, 2022, the Company entered into a swaption for a notional amount of $13,074 with fixed rate of 2.32% with a maturity date of May 31, 2023. The Company accounted for the swaption as an economic hedge and included the change in the fair market value in the condensed consolidated statement of operations.

The two interest rate swaps were designated and qualified as cash flow hedges. The Company uses interest rate swaps for the management of interest rate risk exposure, as an interest rate swap effectively converts a portion of the Company’s debt from a floating to a fixed rate. The interest rate swap is an agreement between the Company and counterparties to pay, in the future, a fixed-rate payment in exchange for the counterparties paying the Company a variable payment. The amount of the net payment obligation is based on the notional amount of the interest rate swap and the prevailing market interest rates. The Company may terminate the interest rate swaps prior to their expiration dates, at which point a realized gain or loss may be recognized, or may be amortized over the original life of the interest rate swap if the hedged debt remains outstanding. The value of the Company’s commitment would increase or decrease based primarily on the extent to which interest rates move against the rate fixed for each swap.

The Company records the fair value of the interest rate swap as an asset or liability on its balance sheet. The effective portion of the swap is recorded in Accumulated other comprehensive income.

Commodity Swap Contracts

The Company utilizes commodity swap contracts to hedge against the unfavorable price fluctuations in market prices of electricity. The Company does not apply hedge accounting to these contracts. As such, unrealized and realized gain (loss) is recognized as a component of Renewable Power revenues in the condensed consolidated statement of operations and Derivative financial asset — current and non-current in the condensed consolidated balance sheets. These are considered to be Level 2 instruments in the fair value hierarchy. By using commodity swaps, the Company exposes itself to credit risk and market risk. Credit risk is the failure of the counterparty to perform under the terms of the swap contract. When the fair value of the swap contract is positive, the counterparty owes the Company creating a credit risk. The Company manages the credit risk by entering into contracts with financially sound counterparties. To mitigate this risk, management monitors counterparty credit exposure on an annual basis, and the necessary credit adjustments have been reflected in the fair value of financial derivative instruments. When the fair value of the swap contract is negative, the Company owes the counterparty creating a market risk that the market price is higher than the contract price resulting in the Company not participating in the opportunity to earn higher revenues.

Fair value measurements

Fair Value Measurements

The fair value of financial instruments, including long-term debt and derivative instruments is defined as the amount at which the instruments could be exchanged in a current transaction between willing parties. 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 Company follows ASC 820, Fair Value Measurement, regarding fair value measurements which establishes a three-tier fair value hierarchy and prioritizes the inputs used in valuation techniques that measure fair value. These tiers include:

Level 1 — defined as observable inputs such as quoted prices for identical instruments in active markets;

Level 2 — defined as quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, or model-derived valuations for which all significant inputs are observable market data;

Level 3 — defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions.

Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company's assessment of the significance of an input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

The Company values its energy commodity swap contracts based on the applicable geographical market energy forward curve. The forward curves are derived based on the quotes provided by New York Mercantile Exchange, Amerex Energy Services and Tradition Energy. The Company does not consider that the pricing index used involves significant judgement on the part of management. Therefore, the Company classifies these commodity swap contracts within Level 2 of the valuation hierarchy based on the observable market rates used to determine fair value.

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 estimates the fair value of asset retirement obligations by calculating the estimated present value of the cost to retire the asset. This estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental, and political environments. In addition, the Company determines the Level 3 fair value measurements based on historical information and current market conditions. These assumptions represent Level 3 inputs, which can regularly change. As such, the fair value measurement of asset retirement obligations is subject to changes in these unobservable inputs as of the measurement date. The Company used a discounted cash flow model in which cash outflows estimated to retire the asset are discounted to their present value using an expected discount rate. A significant increase (decrease) in the discount rate in isolation could result in a significantly lower (higher) fair value measurement.

Variable Interest Entities

We determine whether we are the primary beneficiary of a VIE upon our initial involvement with the VIE and we reassess whether we are the primary beneficiary of a VIE on an ongoing basis. Our determination of whether we are the primary beneficiary of a VIE is based upon the facts and circumstances for each VIE and requires judgment. Our considerations in determining the VIE's most significant activities and whether we have power to direct those activities

include, but are not limited to, the VIE's purpose and design and the risks passed through to investors, the voting interests of the VIE, management, service and/or other agreements of the VIE, involvement in the VIE's initial design, and the existence of explicit or implicit financial guarantees. If we are the party with the power over the most significant activities, we meet the "power" criteria of the primary beneficiary. If we do not have the power over the most significant activities or we determine that all significant decisions require consent of a third party, we do not meet the "power" criteria of the primary beneficiary.

We assess our variable interests in a VIE both individually and in aggregate to determine whether we have an obligation to absorb losses of or a right to receive benefits from the VIE that could potentially be significant to the VIE. The determination of whether our variable interest is significant to the VIE requires judgment. In determining the significance of our variable interest, we consider the terms, characteristics and size of the variable interests, the design and characteristics of the VIE, our involvement in the VIE, and our market-making activities related to the variable interests.

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Summary of Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Schedule of Cash, Cash Equivalents and Restricted Cash

Cash, cash equivalents, and restricted cash consisted of the following as of September 30, 2023 and December 31, 2022:

	September 30, 2023		December 31, 2022
Current assets:
Cash and cash equivalents	$	15,000	$	40,394
Restricted cash - current (1)	1,232		32,402
Long-term assets:
Restricted cash held as collateral (2)	5,356		4,425
Total cash, cash equivalents, and restricted cash	$	21,588	$	77,221

(1) Restricted cash - current as of September 30, 2023 primarily relates to interest reserve on the Sunoma Loan. Restricted cash - current as of December 31, 2022 primarily consists of (i) $16,849 held in escrow to secure the Company's purchase obligations under the forward purchase agreement with Meteora Capital Partners ("Meteora"); (ii) $5,845 equity contribution to a joint venture in connection with the closing of OPAL Term Loan II (iii) $1,127 related to interest reserve on the Sunoma Loan and (iv) $8,581 held in a restricted account for funding one of our RNG projects. The decrease in Restricted cash - current relates to the completed performance of the forward purchase agreement with Meteora and funds spent on construction of our RNG facilities.

(2) Restricted cash held as collateral represents the collateral requirements on our debt facilities.

Schedule of Cash, Cash Equivalents and Restricted Cash

Cash, cash equivalents, and restricted cash consisted of the following as of September 30, 2023 and December 31, 2022:

	September 30, 2023		December 31, 2022
Current assets:
Cash and cash equivalents	$	15,000	$	40,394
Restricted cash - current (1)	1,232		32,402
Long-term assets:
Restricted cash held as collateral (2)	5,356		4,425
Total cash, cash equivalents, and restricted cash	$	21,588	$	77,221

(1) Restricted cash - current as of September 30, 2023 primarily relates to interest reserve on the Sunoma Loan. Restricted cash - current as of December 31, 2022 primarily consists of (i) $16,849 held in escrow to secure the Company's purchase obligations under the forward purchase agreement with Meteora Capital Partners ("Meteora"); (ii) $5,845 equity contribution to a joint venture in connection with the closing of OPAL Term Loan II (iii) $1,127 related to interest reserve on the Sunoma Loan and (iv) $8,581 held in a restricted account for funding one of our RNG projects. The decrease in Restricted cash - current relates to the completed performance of the forward purchase agreement with Meteora and funds spent on construction of our RNG facilities.

(2) Restricted cash held as collateral represents the collateral requirements on our debt facilities.

Changes in the Asset Retirement Obligation

The changes in the asset retirement obligations were as follows as of September 30, 2023:

	September 30, 2023
Balance, December 31, 2022 - Current and non-current	$	6,256
Accretion expense	307
Total asset retirement obligation	6,563
Less: current portion	(1,296)
Total asset retirement obligation, net of current portion	$	5,267

Disaggregation of Revenue By Product Line

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Electricity sales	$	8,929	$	9,666	$	26,925	$	27,205
Third party construction	15,182		18,661		37,429		41,476
Fuel Station Service	4,824		3,480		13,728		11,910
Brown gas sales	1,917		12,430		17,268		23,398
Environmental attributes	38,480		19,648		68,848		58,444
Parts sales	629		1,355		1,965		2,332
Operating agreements	—		—		—		893
Other	—		70		—		236
Total revenue from contracts with customers	69,961		65,310		166,163		165,894
Lease revenue	1,140		1,240		2,937		2,920
Total revenue	$	71,101	$	66,550	$	169,100	$	168,814

Schedule of Other Income

The following table shows the items recorded as Other income:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Loss on warrant exchange	$	—	$	—	$	(338)	$	—
Gain on deconsolidation of VIEs (1)	—		—		122,873		—
Gain on extinguishment of contingent liability	—		4,365		—		4,365
Gain on repayment of Note Receivable	—		1,943		—		1,943
Gain on transfer of non-financial asset in exchange for services received (2)	604		—		1,110		—
Other income	$	604	$	6,308	$	123,645	$	6,308

(1) Represents non-cash gain on deconsolidation of Emerald and Sapphire on May 30, 2023.

(2) Represents the fair value of RINs transferred as consideration for services received.

Receivables, Contract Assets and Contract Liabilities From Contracts With Customers

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

	September 30, 2023		December 31, 2022
Accounts receivable, net	$	31,000	$	31,083
Contract assets:
Cost and estimated earnings in excess of billings	$	10,975	$	7,027
Accounts receivable retainage, net	3,429		2,744
Contract assets total	$	14,404	$	9,771
Contract liabilities:
Billings in excess of costs and estimated earnings	$	7,429	$	8,013
Contract liabilities total	$	7,429	$	8,013

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Investments in Other Entities (Tables)

9 Months Ended

Sep. 30, 2023

Equity Method Investments and Joint Ventures [Abstract]

Summary of Equity Method Investments

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

	Pine Bend			Paragon			Noble Road			GREP			Total
Percentage of ownership	50		%	50		%	50		%	20		%
Balance at December 31, 2022	$	22,518		$	—		$	25,165		$	4,082		$	51,765
Deconsolidation of Emerald and Sapphire	—			34,662			—			—			34,662
Deconsolidation of deferred financing costs and capitalized interest	—			1,383			—			—			1,383
Net income from equity method investment (1)	1,884			(1,190)			3,190			(810)			3,074
Reclassification of adjustments into earnings	—			—			—			(334)			(334)
Contribution by the Company (2)	—			500			—			—			500
Distributions from return of investment in equity method investment	(3,525)			(3,585)			(5,700)			(521)			(13,331)
Accumulated other comprehensive income	—			515			—			—			515
Gain on deconsolidation of Emerald and Sapphire (3)	—			122,873			—			—			122,873
Amortization of basis difference (1)	(218)			(388)			(1,035)			—			(1,641)
Balance at September 30, 2023	$	20,659		$	154,770		$	21,620		$	2,417		$	199,466

(1) Reflected in Income from equity method investments in the condensed consolidated statement of operations for the three and nine months ended September 30, 2023 and 2022.

(2) Represents 50% of the $1,000 contributed by the Company in the third quarter of 2023.

(3) Recorded as part of Other income in our condensed consolidated statement of operations for the three and nine months ended September 30, 2023.

The following table summarizes the net income from equity method investments:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Revenue (1)	$	9,463	$	42,158	$	23,927	$	47,247
Gross profit	(11,268)		33,053		(1,392)		34,665
Net income	4,533		31,356		1,634		29,615
Net income from equity method investments (2)	$	1,726	$	3,694	$	1,433	$	3,658

(1) Revenues include a realized gain of $32,796 from commodity swap contracts on our equity method investment, GREP for the three and nine months ended September 30, 2022.

(2) Net income from equity method investments represents our portion of the net income from equity method investments including amortization of any basis differences.

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Property, Plant, and Equipment, Net (Tables)

9 Months Ended

Sep. 30, 2023

Property, Plant and Equipment [Abstract]

Summary of Property, Plant, and Equipment, Net

Property, plant, and equipment, net, consisted of the following as of September 30, 2023 and December 31, 2022:

	September 30, 2023		December 31, 2022
Plant and equipment	$	203,473	$	201,655
CNG/RNG fueling stations	46,892		34,567
Construction in progress (1)	150,649		152,105
Buildings	2,585		2,585
Land	1,303		1,303
Service equipment	2,207		1,888
Leasehold improvements	815		815
Vehicles	231		313
Office furniture and equipment	307		307
Computer software	277		277
Vehicles - finance leases	1,708		1,236
Other	571		487
	411,018		397,538
Less: accumulated depreciation	(107,328)		(100,215)
Property, plant, and equipment, net	$	303,690	$	297,323

(1) Includes $4,101 and $3,081 of capitalized interest on our OPAL Term Loan facility as of September 30, 2023 and December 31, 2022.

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Intangible Assets, Net (Tables)

9 Months Ended

Sep. 30, 2023

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Intangible Assets with Definite Lives

Intangible assets, net, consisted of the following at September 30, 2023 and December 31, 2022:

	September 30, 2023
	Cost		Accumulated Amortization		Intangible Assets, Net		Weighted Average Amortization Period (Years)
Power purchase agreements	$	8,999	$	(7,889)	$	1,110	18.1
Transmission/distribution interconnection	1,600		(1,019)		581		15.1
Intellectual property	43		(34)		9		5.0
Total intangible assets	$	10,642	$	(8,942)	$	1,700

	December 31, 2022
	Cost		Accumulated Amortization		Intangible Assets, Net		Weighted Average Amortization Period (years)
Power purchase agreements	$	8,999	$	(7,488)	$	1,511	18.1
Transmission/distribution interconnection	1,600		(971)		629		15.1
CNG sales contract	807		(799)		8		10.0
Intellectual property	43		(24)		19		5.0
Total intangible assets	$	11,449	$	(9,282)	$	2,167

Schedule of Estimated Future Amortization Expense For Definite Lived Intangible Assets

At September 30, 2023, estimated future amortization expense for intangible assets is as follows:

For the remainder of the year ending December 31, 2023	$	81
Fiscal year:
2024	267
2025	267
2026	239
2027	238
Thereafter	608
	$	1,700

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Goodwill (Tables)

9 Months Ended

Sep. 30, 2023

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Changes in Goodwill

The following table summarizes the changes in goodwill, if any, by reporting segment from the beginning of the period to the end of the period:

	RNG Fuel		Fuel Station Services		Total
Balance at December 31, 2022	$	51,155	$	3,453	$	54,608
Balance at September 30, 2023	$	51,155	$	3,453	$	54,608

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Borrowings (Tables)

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Schedule of Borrowings

The following table summarizes the borrowings under the various debt facilities as of September 30, 2023 and December 31, 2022:

	September 30, 2023		December 31, 2022
Senior Secured Credit Facility, term loan	$	—	$	15,250
Less: unamortized debt issuance costs	—		—
Less: current portion	—		(15,250)
Senior Secured Credit Facility, term loan, net of debt issuance costs	—		—
Senior Secured Credit Facility, working capital facility	—		7,500
Less: current portion	—		(7,500)
Senior Secured Credit Facility, working capital facility	—		—
OPAL Term Loan	164,118		96,090
Less: unamortized debt issuance costs	(10,492)		(1,758)
Less: current portion	—		(27,732)
OPAL Term Loan, net of debt issuance costs	153,626		66,600
Sunoma Loan	23,000		23,000
Less: unamortized debt issuance costs	(859)		(908)
Less: current portion	(1,739)		(380)
Sunoma Loan, net of debt issuance costs	20,402		21,712
Convertible Note Payable	—		28,528
Less: current portion	—		(28,528)
Convertible Note Payable	—		—
Municipality Loan	—		76
Less: current portion	—		(76)
Municipality Loan	—		—
Non-current borrowings total	$	174,028	$	88,312

Schedule of Principal Maturities of Debt

As of September 30, 2023, principal maturities of debt are expected as follows, excluding any subsequent refinancing transactions and any undrawn debt facilities as of the date of the condensed consolidated balance sheets:

	OPAL Term Loan		Sunoma Loan		Total
For the remainder of the year ending December 31, 2023	$	—	$	533	$	533
Fiscal year:
2024	—		1,620		1,620
2025	14,771		1,756		16,527
2026	19,694		1,898		21,592
2027	129,653		17,193		146,846
	$	164,118	$	23,000	$	187,118

Schedule of Interest Expense on Borrowings

The following table summarizes the Company's total interest expense for the three and nine months ended September 30, 2023 and 2022:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Senior Secured Credit Facility	$	—	$	(1,101)	$	(282)	$	(2,543)
Convertible Note Payable mark-to-market	(436)		2,261		(1,579)		151
Sunoma Loan	(454)		(424)		(1,348)		(1,335)
OPAL Term Loan (1)	(1,634)		(1,107)		(1,653)		(2,850)
Commitment fees and other finance fees	(248)		(401)		(560)		(605)
Amortization of deferred financing cost	(652)		(616)		(1,447)		(1,514)
Interest expense on finance leases	(24)		(15)		(61)		(28)
Interest income	563		613		2,448		1,512
Total interest expense	$	(2,885)	$	(790)	$	(4,482)	$	(7,212)

(1) Excludes $842 and $4,627 of interest capitalized and recorded as part of Property, Plant and Equipment for the three and nine months ended September 30, 2023, respectively.

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Leases (Tables)

9 Months Ended

Sep. 30, 2023

Leases [Abstract]

Right-Of-Use Assets And Lease Liabilities

Right-of-use assets and Lease liabilities as of September 30, 2023 and December 31, 2022 are as follows:

Description	Location in Balance Sheet	September 30, 2023		December 31, 2022
Assets:
Operating leases (1):
Site leases	Right-of-use assets	$	11,287	$	10,338
Office lease	Right-of-use assets	1,081		1,406
		12,368		11,744
Finance leases (1):
Vehicle leases	Property, plant and equipment, net	1,708		1,236
		14,076		12,980
Liabilities (1):
Sites leases	Lease liabilities - current portion	126		181
Office lease	Lease liabilities - current portion	499		449
Vehicle leases	Accrued expenses and other current liabilities	577		449
		1,202		1,079
Sites leases	Lease liabilities - non-current portion	11,168		10,135
Office lease	Lease liabilities - non-current portion	731		1,110
Vehicle leases	Other long-term liabilities	1,131		825
		$	13,030	$	12,070

(1) The Operating lease right-of-use asset and Operating lease liabilities represent the present value of lease payments for the remaining term of the lease. The discount rate used ranged from 2.30% to 8.44%.

The table below presents components of the Company's lease expense for the three and nine months ended September 30, 2023 and 2022:

Description	Location in Statement of Operations	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Operating lease expense for site leases	Cost of sales - RNG Fuel	$	263	$	261	$	789	$	785
Operating lease expense for office lease	Selling, general, administrative expenses	121		121		363		363
Amortization of right-of-use assets - finance leases	Depreciation, amortization and accretion expense	155		81		436		245
Interest expense on lease liabilities - finance leases	Interest and financing expense, net	24		15		61		28
		$	563	$	478	$	1,649	$	1,421

The Company does not have material short term lease expense for the three and nine months ended September 30, 2023 and 2022.

Weighted average remaining lease term (years)	September 30, 2023
Operating leases	19.1 years
Financing leases	3.1 years
Weighted average discount rate
Operating leases	7.84	%
Financing leases	6.39	%

Future Minimum Lease Payments - Operating Leases

The table below provides the total amount of lease payments on an undiscounted basis on our lease contracts as of September 30, 2023:

	Site leases			Office leases			Vehicle leases			Total
Discount rate upon adoption	5.4		%	2.3		%	7.6		%
2023	$	261		$	130		$	147		$	538
2024	1,058			540			667			2,265
2025	1,129			562			561			2,252
2026	1,129			47			406			1,582
2027 and beyond	20,145			—			115			20,260
	23,722			1,279			1,896			26,897
Present value of lease liability	11,294			1,230			1,708			14,232
Lease liabilities - current portion	126			499			577			1,202
Lease liabilities - non-current portion	11,168			731			1,131			13,030
Total lease liabilities	$	11,294		$	1,230		$	1,708		$	14,232
Discount based on incremental borrowing rate	$	12,428		$	49		$	188		$	12,665

Future Minimum Lease Payments - Finance Leases

The table below provides the total amount of lease payments on an undiscounted basis on our lease contracts as of September 30, 2023:

	Site leases			Office leases			Vehicle leases			Total
Discount rate upon adoption	5.4		%	2.3		%	7.6		%
2023	$	261		$	130		$	147		$	538
2024	1,058			540			667			2,265
2025	1,129			562			561			2,252
2026	1,129			47			406			1,582
2027 and beyond	20,145			—			115			20,260
	23,722			1,279			1,896			26,897
Present value of lease liability	11,294			1,230			1,708			14,232
Lease liabilities - current portion	126			499			577			1,202
Lease liabilities - non-current portion	11,168			731			1,131			13,030
Total lease liabilities	$	11,294		$	1,230		$	1,708		$	14,232
Discount based on incremental borrowing rate	$	12,428		$	49		$	188		$	12,665

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Derivative Financial Instruments and Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Interest Rate Swaps

The following table summarizes the interest rate swaps in place as of September 30, 2023 and December 31, 2022:

Interest rate swap detail					Notional Amount
Trade date	Fixed rate		Start date	End date	September 30, 2023		December 31, 2022
August 15, 2022	2.47	%	June 28, 2024	August 4, 2027	$	—	41,284
August 15, 2022	2.47	%	June 28, 2024	August 4, 2027	—		20,642
					$	—	$	61,926

Derivatives Fair Values on Balance Sheet

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

	September 30, 2023		December 31, 2022		Location of Fair Value Recognized in Balance Sheet
Derivatives designated as economic hedges:
Current portion of swaption	$	—	$	182	Derivative financial assets, current portion
Derivatives designated as cash flow hedges:
Long term portion of the interest rate swaps	—		954		Derivative financial assets, non-current
	$	—	$	1,136

The following table summarizes the derivative assets and liabilities related to commodity swaps as of September 30, 2023 and December 31, 2022:

	Fair Value				Location of Fair value recognized in Balance Sheet
	September 30, 2023		December 31, 2022
Derivatives designated as economic hedges
Current portion of unrealized gain on commodity swaps	$	486	$	—	Derivative financial asset, current portion
Non-current portion of unrealized gain on commodity swaps	$	117	$	—	Derivative financial asset, non-current portion
Current portion of unrealized loss on commodity swaps	$	—	$	(130)	Derivative financial liability, current portion

Effect of Derivative Instruments on Statement of Operations

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

	Three Months Ended September 30,				Nine Months Ended September 30,				Location of (Loss) Gain Recognized in Operations from Derivatives
	2023		2022		2023		2022
Interest rate swaps	$	—	$	1,580	$	—	$	954
Swaption	—		246		(46)		246
Net periodic settlements	—		(1,631)		812		(677)
	$	—	$	195	$	766	$	523	Change in fair value of derivative instruments, net

The following table summarizes the effect of commodity swaps on the condensed consolidated statements of operations for the three and nine months ended September 30, 2023 and 2022:

Derivatives not designated as hedging instruments	Location of (loss) gain recognized	Three Months Ended September 30,				Nine Months Ended September 30,
		2023		2022		2023		2022
Commodity swaps - realized (loss) gain	Revenues - Renewable power	$	493	$	(744)	$	1,373	$	(931)
Commodity swaps - unrealized gain (loss)	Revenues - Renewable power	(30)		161		733		(775)
Total realized and unrealized gain (loss)	Revenues - Renewable power	$	463	$	(583)	$	2,106	$	(1,706)

Fair Value of Derivative Instruments on Balance Sheet and Effect of Netting Arrangements

The following table summarizes the fair value of derivative instruments on the Company's condensed consolidated balance sheets and the effect of netting arrangements and collateral on its financial position:

	Gross Amounts of Recognized Assets		Gross Amounts Offset in the Balance Sheet		Net Amounts of Assets in the Balance Sheet
Balance, September 30, 2023:
Interest rate swap asset	$	—	$	—	$	—
Swaption asset	—		—		—
	$	—	$	—	$	—
Balance, December 31, 2022:
Interest rate swap asset	$	954	$	—	$	954
Swaption asset	182		—		182
	$	1,136	$	—	$	1,136

Fair Value of Derivative Instruments on Balance Sheet and Effect of Netting Arrangements

The following table summarizes the fair value of derivative instruments on the Company's condensed consolidated balance sheets and the effect of netting arrangements and collateral on its financial position:

	Gross Amounts of Recognized Assets		Gross Amounts Offset in the Balance Sheet		Net Amounts of Assets in the Balance Sheet
Balance, September 30, 2023:
Interest rate swap asset	$	—	$	—	$	—
Swaption asset	—		—		—
	$	—	$	—	$	—
Balance, December 31, 2022:
Interest rate swap asset	$	954	$	—	$	954
Swaption asset	182		—		182
	$	1,136	$	—	$	1,136

Summary of Commodity Swaps And Other Derivatives

The following table summarizes the commodity swaps in place as of September 30, 2023 and December 31, 2022. There were no new commodity swap contracts entered during the three months ended September 30, 2023.

Trade Date	Period From	Period To	Notional Quantity per Year (“MWh”)	Average Contract Price (per MWh)
October 17, 2022	January 1, 2023	December 31, 2024	70,176	$	68.50
October 17, 2022	January 1, 2023	December 31, 2024	26,280	$	65.50
November 17, 2022	January 1, 2023	December 31, 2024	35,088	$	81.50

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 September 30, 2023 and 2022:

Derivative liability	Three Months Ended September 30,				Nine Months Ended September 30,				Location of (Loss) Gain Recognized in Operations from Derivatives
	2023		2022		2023		2022
Put option to Meteora	$	—	$	384	$	(311)	$	384
Sponsor Earnout Awards	(338)		1,100		(201)		1,100
OPAL Earnout Awards	200		5,300		4,701		5,300
Public Warrants	—		(3,578)		—		(3,578)
Private Warrants	—		(5,309)		—		(5,309)
	$	(138)	$	(2,103)	$	4,189	$	(2,103)	Change in fair value of derivative instruments, net

Assets and Liabilities Measured at Fair Value on Recurring Basis

The Company's assets and liabilities that are measured at fair value on a recurring basis include the following as of September 30, 2023 and December 31, 2022, set forth by level, within the fair value hierarchy:

	Fair value as of September 30, 2023
	Level 1		Level 2		Level 3		Total
Liabilities:
Asset retirement obligation	$	—	$	—	$	6,563	$	6,563
Earnout liabilities	—		—		4,291		4,291
Assets:
Short term investments	18,028		—		—		18,028
Commodity swap contracts	—		603		—		603

	Fair value as of December 31, 2022
	Level 1		Level 2		Level 3		Total
Liabilities:
Asset retirement obligation	$	—	$	—	$	6,256	$	6,256
Convertible Note Payable (1)	—		28,528				28,528
Put option with Meteora	—		—		4,466		4,466
Commodity swap contracts	—		130		—		130
Earnout liabilities	—		—		8,790		8,790
Assets:
Short term investments	64,976		—		—		64,976
Swaption	—		182		—		182
Commodity swap contracts	—		954		—		954

(1) The fair value of the Convertible Note Payable as of December 31, 2022, represents the outstanding principal and paid-in-kind interest. Therefore it did not have any unobservable inputs which required the Company to develop its own assumptions. The methodology for calculating the fair value has changed as of December 31, 2022 as the prepayment penalty was cancelled upon consummation of Business Combination. Therefore, the Convertible Note Payable has been transferred from Level 3 to Level 2.

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Related Parties (Tables)

9 Months Ended

Sep. 30, 2023

Related Party Transactions [Abstract]

Fees Upon Entering Into Management Services Agreement with Related Party

The following table summarizes the various fees recorded under the agreements described above which are included in "Selling, general, and administrative" expenses:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Staffing and management services	$	414	$	578	$	1,406	$	1,683
Rent - fixed compensation	166		168		494		442
IT services	754		636		2,210		1,721
Total	$	1,334	$	1,382	$	4,110	$	3,846

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Reportable Segments and Geographic Information (Tables)

9 Months Ended

Sep. 30, 2023

Segment Reporting [Abstract]

Schedule of Total Revenues by Segment

The Company has determined that each of the four operating segments meets the characteristics of a reportable segment under U.S. GAAP. The Company's activities and assets that are not associated with the four reportable segments are summarized in the "Other" category below. These include corporate investment income, interest income and interest expense, income tax expense, and other non-allocated costs.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Revenues:
Renewable Power	$	13,708	$	49,737	$	43,543	$	70,937
RNG Fuel	29,551		22,788		61,395		61,971
Fuel Station Services	40,326		39,333		99,056		91,325
Intersegment	(3,021)		(3,150)		(10,967)		(8,172)
Equity Method Investment(s)	(9,463)		(42,158)		(23,927)		(47,247)
	$	71,101	$	66,550	$	169,100	$	168,814

Schedule of Interest Expense on Borrowings, Depreciation, Amortization and Accretion and Cash Paid for Purchases, Plant and Equipment

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Interest and Financing Expense, Net:
Renewable Power	$	(2)	$	(1,440)	$	(260)	$	(3,559)
RNG Fuel	(3,243)		(189)		(4,616)		(240)
Fuel Station Services	27		(14)		120		(28)
Corporate	333		853		274		(3,385)
	$	(2,885)	$	(790)	$	(4,482)	$	(7,212)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Depreciation, Amortization, and Accretion:
Renewable Power	$	1,488	$	1,176	$	4,389	$	4,283
RNG Fuel	2,492		2,461		6,808		6,379
Fuel Station Services	917		411		2,555		616
Other(1)	9		31		36		95
Equity Method Investment(s)	(1,167)		(699)		(2,854)		(1,272)
	$	3,739	$	3,380	$	10,934	$	10,101

(1)Other includes amortization of intangible assets and depreciation expense not allocated to any segment.

	Nine Months Ended September 30,
	2023		2022
Cash paid for Purchases of Property, Plant, and Equipment:
Renewable Power	$	—	$	1,800
Fuel Station Services	16,860		7,038
RNG Fuel	75,390		76,496
	$	92,250	$	85,334

Schedule of Net Income (Loss)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Net income (loss)
Renewable Power	$	983	$	3,483	$	10,584	$	1,314
RNG Fuel	10,821		5,669		8,044		21,775
Fuel Station Services	5,530		11,624		7,429		12,574
Corporate	(18,833)		(19,101)		79,441		(38,761)
Equity Method Investment(s)	1,726		3,694		1,433		3,658
	$	227	$	5,369	$	106,931	$	560

Total Assets

	September 30, 2023		December 31, 2022
Total Assets:
Renewable Power	$	39,503	$	43,468
RNG Fuel	290,247		347,750
Fuel Station Services	131,838		119,669
Corporate	29,401		82,204
Equity Method Investment(s)	199,466		51,765
	$	690,455	$	644,856

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Variable Interest Entities (Tables)

9 Months Ended

Sep. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Variable Interest Entities

The amount of assets that can only be used to settle obligations of the VIEs are parenthesized in the condensed consolidated balance sheets and are included in the asset totals listed in the table below.

	As of September 30, 2023		As of December 31, 2022
Assets
Current assets:
Cash and cash equivalents	$	1,302	$	12,506
Accounts receivable, net	79		966
Restricted cash - current	1,232		6,971
Environmental credits held for sale	29		—
Prepaid expenses and other current assets	193		415
Total current assets	2,835		20,858
Property, plant and equipment, net	26,684		73,140
Restricted cash, non-current	2,843		2,923
Total assets	$	32,362	$	96,921
Liabilities and equity
Current liabilities:
Accounts payable	$	603	$	4,896
Accounts payable, related party	1,035		433
Accrued capital expenses	—		7,821
Accrued expenses	602		646
Sunoma Loan- current portion	1,739		380
Total current liabilities	3,979		14,176
Sunoma loan, net of debt issuance costs	20,402		21,712
Total liabilities	24,381		35,888
Equity
Stockholders' equity	7,097		34,588
Non-redeemable non-controlling interests	884		26,445
Total equity	7,981		61,033
Total Liabilities and Equity	$	32,362	$	96,921

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Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Deficit (Tables)

9 Months Ended

Sep. 30, 2023

Equity [Abstract]

Changes in Redeemable Preferred Units

The following table summarizes the changes in the redeemable preferred non-controlling interests which represent Series A and Series A-1 preferred units outstanding at OPAL Fuels level from December 31, 2022 to September 30, 2023:

	Series A-1 preferred units			Series A preferred units
	Units	Amount		Units	Amount		Total
Balance, December 31, 2022	300,000	$	32,736	1,000,000	$	105,406	$	138,142
Series A units issued by OPAL Fuels	—	—		—	—		—
Paid-in-kind dividends attributable to OPAL Fuels	—	320		—	1,032		1,352
Paid-in kind dividends attributable to Class A common stockholders	—	1,666		—	5,376		7,042
Repayment of paid-in-kind preferred dividends	—	(4,722)		—	$	(11,814)	(16,536)
Balance, September 30, 2023	300,000	$	30,000	1,000,000	$	100,000	$	130,000

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Stock-based compensation (Tables)

9 Months Ended

Sep. 30, 2023

Share-Based Payment Arrangement [Abstract]

Summary of Equity Awards

A summary of the equity awards under the 2022 Plan for the nine months ended September 30, 2023 is as follows:

	Number of Units outstanding	Weighted Average Grant Date Fair Value		Aggregate Fair Value (in thousands)
Restricted Stock Units:
Unvested awards as of December 31, 2022	422,349	$	7.94
Granted	1,038,347	6.98
Vested in August 2023	(2,135)	6.97
Shares withheld for settlement of taxes	(1,046)
Forfeitures	(50,378)	7.49
Restricted Stock Units outstanding as of September 30, 2023	1,407,137	$	7.31	$	10,284
Stock Options:
Unvested awards as of December 31, 2022	—	—
Granted	196,961	$	5.26
Stock Options outstanding as of September 30, 2023	196,961	$	5.26	$	1,036
Performance Stock Units:
Unvested awards as of December 31, 2022	—
Granted	274,617	$	6.97
Vested in August 2023	(83)
Shares withheld for settlement of taxes	(31)
Forfeitures	(3,975)	$	6.97
Performance Stock Units outstanding as of September 30, 2023	270,528	$	6.97	$	1,553
Total unvested awards outstanding as of September 30, 2023	1,874,626	$	6.87	$	12,873

Stock-based Compensation Expense

Stock-based compensation expense for all stock awards included in Selling, general and administrative expenses:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
Stock-based compensation expense	$	1,899	$	160	$	4,747	$	320
	$	1,899	$	160	$	4,747	$	320

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Net (Loss) Income Per Share (Tables)

9 Months Ended

Sep. 30, 2023

Earnings Per Share [Abstract]

Schedule of Basic and Diluted Net Loss Per Unit

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

	Three Months Ended		Nine Months Ended
	September 30, 2023		September 30, 2023
Net (loss) income attributable to Class A common stockholders	(400)		$	15,945
Weighted average number of shares of Class A common stock - basic	26,978,969		27,110,953
Dilutive effect of stock options, restricted stock units, performance units, Convertible note payable, earnout shares, Redeemable preferred non-controlling interests, Redeemable non-controlling interests	—		572,902
Weighted average number of shares of Class A common stock - diluted	26,978,969		27,683,855
Net loss per share of Class A common stock
Basic	$	(0.01)	$	0.59
Diluted	$	(0.01)	$	0.58

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Organization and Description of Business (Details)	9 Months Ended
	Sep. 30, 2023 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of operating segments	4

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Summary of Significant Accounting Policies - Narrative (Details) $ / shares in Units, $ in Thousands							3 Months Ended				6 Months Ended	9 Months Ended		12 Months Ended	14 Months Ended
	Sep. 14, 2023 project	Jan. 26, 2023 shares	Jan. 23, 2023 USD ($) $ / shares shares	Jul. 21, 2022 USD ($) $ / shares shares	Jul. 20, 2022 shares	Nov. 29, 2021 project	Dec. 31, 2023 facility	Sep. 30, 2023 USD ($) variable_interest_entity producer facility	Mar. 31, 2023 USD ($) $ / shares shares	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($) variable_interest_entity subsidiary	Sep. 30, 2023 USD ($) facility variable_interest_entity producer	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($) variable_interest_entity shares	Sep. 30, 2023 USD ($) variable_interest_entity producer	May 30, 2023 deconsolidated_entity	May 29, 2023 variable_interest_entity
Revenue from External Customer [Line Items]
Number of deconsolidated entities | deconsolidated_entity																2
Number of variable interest entities consolidated | variable_interest_entity								2			4	2		4	2		2
Number of noncontrolling interests in renewable natural gas project subsidiaries | project						4
Restricted cash held in escrow											$ 16,849			$ 16,849
Cash held in restricted account											8,581			8,581
Short term investments								$ 18,028			64,976	$ 18,028		64,976	$ 18,028
Contingent consideration (in shares) | shares				10,000,000
Gain on Earnout Awards								(138)		$ 6,400		4,499	$ 6,400
Earn out liabilities								4,291			8,790	4,291		$ 8,790	4,291
Stock issued (in shares) | shares														1,000,000
Fair value of shares acquired									$ 11,614
Allowance for doubtful accounts								0			0	0		$ 0	0
Estimated value of total asset retirement obligation								$ 6,563			$ 6,256	$ 6,563		6,256	$ 6,563
Number of natural gas producers | producer								2				2			2
Net revenues								$ 71,101		66,550		$ 169,100	168,814
Revenue recognized included in contract liabilities												8,013	9,785
Backlog								46,549				46,549			$ 46,549
Renewable Power
Revenue from External Customer [Line Items]
Net revenues								13,708		12,486		43,543	32,623
Number of subsidiaries wholly-owned | subsidiary											2
Renewable Power | Related Party
Revenue from External Customer [Line Items]
Net revenues								$ 1,732		927		$ 5,006	$ 3,196
New Jersey
Revenue from External Customer [Line Items]
Number of noncontrolling interests in renewable natural gas project subsidiaries | project	2
Paragon
Revenue from External Customer [Line Items]
Percentage of ownership								50.00%				50.00%			50.00%	50.00%
OPAL L2G
Revenue from External Customer [Line Items]
Percentage of ownership	50.00%
SJI LRNG
Revenue from External Customer [Line Items]
Percentage of ownership	50.00%
SJI LRNG | New Jersey
Revenue from External Customer [Line Items]
Percentage of ownership	50.00%
Class D common stock | Opal Fuels
Revenue from External Customer [Line Items]
Stock issued (in shares) | shares				144,399,037
Redeemable non-controlling interests
Revenue from External Customer [Line Items]
Change in redemption value of Redeemable non-controlling interests								$ 90,834	$ 7,720	$ 1,160,723					$ 1,158,937
Sponsor Letter Agreement
Revenue from External Customer [Line Items]
Percentage of common stock subject to vesting and forfeiture conditions				10.00%
Common stock subject to vesting and forfeiture conditions, period				60 months
Sunoma Loan
Revenue from External Customer [Line Items]
Interest reserve											$ 1,127			1,127
Opal Term Loan II | Secured Debt
Revenue from External Customer [Line Items]
Contribution to joint venture											$ 5,845			$ 5,845
Emerald And Sapphire | Paragon
Revenue from External Customer [Line Items]
Percentage of ownership transferred																50.00%
Meteora | Forward Purchase Agreement
Revenue from External Customer [Line Items]
Contingent consideration (in shares) | shares				2,000,000
Contingent consideration, escrow			$ 16,391	$ 20,040
Contingent consideration, price (in dollars per share) | $ / shares				$ 10.02					$ 10.02
Contingent consideration period				6 months
Fair value of shares acquired			$ 11,614									$ 11,614
Closing share price (in dollars per share) | $ / shares			$ 7.01
Offset to derivative liabilities								$ 4,777				$ 4,777			$ 4,777
Meteora | Forward Purchase Agreement | ArcLight Class A Common STock
Revenue from External Customer [Line Items]
Stock issued (in shares) | shares			1,635,783		2,000,000				1,635,783
Sponsor | Class A common stock
Revenue from External Customer [Line Items]
Forfeited shares (in shares) | shares		197,258
Accounts Payable | Supplier Concentration Risk | Two Vendors
Revenue from External Customer [Line Items]
Concentration risk percentage												39.00%
Accounts Payable | Supplier Concentration Risk | One Vendor
Revenue from External Customer [Line Items]
Concentration risk percentage														19.00%
Two Customers | Revenue Benchmark | Customer Concentration Risk
Revenue from External Customer [Line Items]
Concentration risk percentage								49.00%		49.00%		41.00%	45.00%
Two Customers | Accounts Receivable | Customer Concentration Risk
Revenue from External Customer [Line Items]
Concentration risk percentage														44.00%
One Customer | Accounts Receivable | Customer Concentration Risk
Revenue from External Customer [Line Items]
Concentration risk percentage												22.00%
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue from External Customer [Line Items]
Backlog recognition period (in months)								12 months				12 months			12 months
Transferred over Time
Revenue from External Customer [Line Items]
Percentage of revenue recognized over time								21.40%		28.00%		22.10%	24.60%
RNG Fuel
Revenue from External Customer [Line Items]
Contract term (in years)								3 years
Number of facilities | facility								2				2
RNG Fuel | Forecast
Revenue from External Customer [Line Items]
Number of facilities that are expected to receive certification | facility							2
RNG Fuel | NextEra
Revenue from External Customer [Line Items]
Minimum of environmental attributes to be sold, percentage						90.00%
RNG Fuel | NextEra | Related Party
Revenue from External Customer [Line Items]
Minimum of environmental attributes to be sold, percentage						90.00%
Natural Gas, Renewable And Fuel Station Services | NextEra | Related Party
Revenue from External Customer [Line Items]
Net revenues								$ 25,724		$ 19,336		$ 43,784	$ 49,024
Environmental attributes | OCI
Revenue from External Customer [Line Items]
Contract term (in years)											3 years
Environmental attributes | OCI | Renewable Power
Revenue from External Customer [Line Items]
Net revenues								$ 3,732		$ 842		$ 13,425	$ 842

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Summary of Significant Accounting Policies - Cash, Cash Equivalents and Restricted Cash (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 15,000	$ 40,394
Restricted cash - current	1,232	32,402
Long-term assets:
Restricted cash held as collateral	5,356	4,425
Total cash, cash equivalents, and restricted cash	$ 21,588	$ 77,221	$ 71,360	$ 42,054

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Summary of Significant Accounting Policies - Changes in the Asset Retirement Obligation (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation, beginning balance	$ 6,256
Accretion expense	307	$ 235
Asset retirement obligation, ending balance	6,563
Less: current portion	(1,296)		$ (1,296)
Total asset retirement obligation, net of current portion	$ 5,267		$ 4,960

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Summary of Significant Accounting Policies - Disaggregation of Revenue By Product Line (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 69,961	$ 65,310	$ 166,163	$ 165,894
Lease revenue	1,140	1,240	2,937	2,920
Total revenues	71,101	66,550	169,100	168,814
Electricity sales
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	8,929	9,666	26,925	27,205
Third party construction
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	15,182	18,661	37,429	41,476
Fuel Station Service
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	4,824	3,480	13,728	11,910
Brown gas sales
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,917	12,430	17,268	23,398
Environmental attributes
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	38,480	19,648	68,848	58,444
Parts sales
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	629	1,355	1,965	2,332
Operating agreements
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	893
Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 0	$ 70	$ 0	$ 236

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Summary of Significant Accounting Policies - Other Income (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Mar. 31, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Accounting Policies [Abstract]
Loss on warrant exchange	$ (338)	$ 0	$ 0	$ (338)	$ 0
Gain on deconsolidation of VIEs		0	0	122,873	0
Gain on extinguishment of contingent liability		0	4,365	0	4,365
Gain on repayment of Note Receivable		0	1,943	0	1,943
Gain on transfer of non-financial asset in exchange for services rendered		604	0	1,110	0
Other income		$ 604	$ 6,308	$ 123,645	$ 6,308

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Summary of Significant Accounting Policies - Receivables, Contract Assets and Contract Liabilities From Contracts With Customers (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Accounts receivable	$ 31,000	$ 31,083
Contract assets:
Cost and estimated earnings in excess of billings	10,975	7,027
Accounts receivable retainage, net	3,429	2,744
Contract assets	14,404	9,771
Contract liabilities:
Billings in excess of costs and estimated earnings	7,429	8,013
Contract liabilities	$ 7,429	8,013
Nonrelated Party
Disaggregation of Revenue [Line Items]
Accounts receivable		$ 31,083

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Investments in Other Entities - Narrative (Details) $ in Thousands				1 Months Ended	3 Months Ended		9 Months Ended
	Sep. 14, 2023 project	May 30, 2023 USD ($) deconsolidated_entity	Nov. 29, 2021 project	Aug. 31, 2021 USD ($)	Sep. 30, 2023 USD ($) variable_interest_entity	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) variable_interest_entity	Sep. 30, 2022 USD ($)	May 29, 2023 variable_interest_entity	Dec. 31, 2022 USD ($) variable_interest_entity
Schedule of Equity Method Investments [Line Items]
Number of noncontrolling interests in renewable natural gas project subsidiaries | project			4
Number of variable interest entities consolidated | variable_interest_entity					2		2		2	4
Capitalized interest deconsolidated		$ 2,765
Number of deconsolidated entities | deconsolidated_entity		2
Gain on deconsolidation of VIEs					$ 0	$ 0	$ 122,873	$ 0
Note receivable - variable fee component					$ 2,178		$ 2,178			$ 1,942
New Jersey
Schedule of Equity Method Investments [Line Items]
Number of noncontrolling interests in renewable natural gas project subsidiaries | project	2
Discount rate
Schedule of Equity Method Investments [Line Items]
Measurement input		14.00%
RNG Fuel
Schedule of Equity Method Investments [Line Items]
Number of deconsolidated entities | deconsolidated_entity		2
OPAL L2G
Schedule of Equity Method Investments [Line Items]
Percentage of ownership	50.00%
SJI LRNG
Schedule of Equity Method Investments [Line Items]
Percentage of ownership	50.00%
SJI LRNG | New Jersey
Schedule of Equity Method Investments [Line Items]
Percentage of ownership	50.00%
Paragon
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		50.00%			50.00%		50.00%
Gain on deconsolidation of VIEs							$ 122,873
Paragon | Emerald And Sapphire
Schedule of Equity Method Investments [Line Items]
Percentage of ownership transferred		50.00%
Reynolds
Schedule of Equity Method Investments [Line Items]
Percentage of ownership interest acquired				100.00%
Reynolds
Schedule of Equity Method Investments [Line Items]
Note receivable				$ 10,450
Interest rate of note receivable				12.50%
Percentage of note receivable payable in cash				8.00%
Payment-in-kind interest of equity method investment				4.50%
Percentage of revenue based distributions of note receivable				4.25%
Maximum amount of revenue based distributions over term of debt				$ 4,500
Note receivable - variable fee component				$ 1,538
Decrease in interest and financing expense					$ 81	$ 73	$ 236	$ 209

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Investments in Other Entities - Summary of Equity Method Investments (Details) - USD ($) $ in Thousands		3 Months Ended			9 Months Ended
		Sep. 30, 2023	Jun. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	May 30, 2023	Aug. 31, 2021
Increase (Decrease) In Equity Method Investments [Roll Forward]
Beginning balance					$ 51,765
Deconsolidation	[1]		$ 36,045
Net income from equity method investment					3,074
Reclassification of adjustments into earnings					(334)
Contribution by the Company		$ (500)			500
Distributions from return of investment in equity method investment					(13,331)
Accumulated other comprehensive income					515
Gain on deconsolidation of Emerald and Sapphire		0		$ 0	122,873	$ 0
Amortization of basis difference					(1,641)
Ending balance		$ 199,466			$ 199,466
Percentage of $1,000 contributed					50.00%
Emerald And Sapphire
Increase (Decrease) In Equity Method Investments [Roll Forward]
Deconsolidation					$ 34,662
Deferred Financing Costs And Capitalized Interest
Increase (Decrease) In Equity Method Investments [Roll Forward]
Deconsolidation					$ 1,383
Pine Bend
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		50.00%			50.00%
Increase (Decrease) In Equity Method Investments [Roll Forward]
Beginning balance					$ 22,518
Net income from equity method investment					1,884
Reclassification of adjustments into earnings					0
Contribution by the Company					0
Distributions from return of investment in equity method investment					(3,525)
Accumulated other comprehensive income					0
Gain on deconsolidation of Emerald and Sapphire					0
Amortization of basis difference					(218)
Ending balance		$ 20,659			20,659
Pine Bend | Emerald And Sapphire
Increase (Decrease) In Equity Method Investments [Roll Forward]
Deconsolidation					0
Pine Bend | Deferred Financing Costs And Capitalized Interest
Increase (Decrease) In Equity Method Investments [Roll Forward]
Deconsolidation					$ 0
Paragon
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		50.00%			50.00%		50.00%
Increase (Decrease) In Equity Method Investments [Roll Forward]
Beginning balance					$ 0
Net income from equity method investment					(1,190)
Reclassification of adjustments into earnings					0
Contribution by the Company					500
Distributions from return of investment in equity method investment					(3,585)
Accumulated other comprehensive income					515
Gain on deconsolidation of Emerald and Sapphire					122,873
Amortization of basis difference					(388)
Ending balance		$ 154,770			154,770
Paragon | Emerald And Sapphire
Increase (Decrease) In Equity Method Investments [Roll Forward]
Deconsolidation					34,662
Paragon | Deferred Financing Costs And Capitalized Interest
Increase (Decrease) In Equity Method Investments [Roll Forward]
Deconsolidation					$ 1,383
Noble Road
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		50.00%			50.00%
Increase (Decrease) In Equity Method Investments [Roll Forward]
Beginning balance					$ 25,165
Net income from equity method investment					3,190
Reclassification of adjustments into earnings					0
Contribution by the Company					0
Distributions from return of investment in equity method investment					(5,700)
Accumulated other comprehensive income					0
Gain on deconsolidation of Emerald and Sapphire					0
Amortization of basis difference					(1,035)
Ending balance		$ 21,620			21,620
Noble Road | Emerald And Sapphire
Increase (Decrease) In Equity Method Investments [Roll Forward]
Deconsolidation					0
Noble Road | Deferred Financing Costs And Capitalized Interest
Increase (Decrease) In Equity Method Investments [Roll Forward]
Deconsolidation					$ 0
GREP
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		20.00%			20.00%			20.00%
Increase (Decrease) In Equity Method Investments [Roll Forward]
Beginning balance					$ 4,082
Net income from equity method investment					(810)
Reclassification of adjustments into earnings					(334)
Contribution by the Company					0
Distributions from return of investment in equity method investment					(521)
Accumulated other comprehensive income					0
Gain on deconsolidation of Emerald and Sapphire					0
Amortization of basis difference					0
Ending balance		$ 2,417			2,417
GREP | Emerald And Sapphire
Increase (Decrease) In Equity Method Investments [Roll Forward]
Deconsolidation					0
GREP | Deferred Financing Costs And Capitalized Interest
Increase (Decrease) In Equity Method Investments [Roll Forward]
Deconsolidation					$ 0

[1] As of May 30, 2023, two of our RNG facilities, Emerald and Sapphire (defined below) were deconsolidated and accounted for under equity method as per ASC 323. Please see Note 4 Investment in Other entities and Note 12 Variable Interest Entities for additional information.

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Investments in Other Entities - Summary of Net Income (Loss) From Equity Method Investments (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Schedule of Equity Method Investments [Line Items]
Total revenues	$ 71,101	$ 66,550	$ 169,100	$ 168,814
Net income	227	5,369	106,931	560
Net income (loss) from equity method investments	1,726	3,694	1,433	3,658
Equity Method Investment(s)
Schedule of Equity Method Investments [Line Items]
Total revenues	9,463	42,158	23,927	47,247
Gross profit	(11,268)	33,053	(1,392)	34,665
Net income	$ 4,533	31,356	$ 1,634	29,615
GREP
Schedule of Equity Method Investments [Line Items]
Commodity swaps - realized (loss) gain		$ 32,796		$ 32,796

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Property, Plant, and Equipment, Net - Summary of Property, Plant, and Equipment, Net (Details) - USD ($) $ in Thousands		9 Months Ended	12 Months Ended
	May 30, 2023	Sep. 30, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Vehicles - finance leases		$ 1,708	$ 1,236
Gross property, plant, equipment and finance leases		411,018	397,538
Less: accumulated depreciation		(107,328)	(100,215)
Property, plant, and equipment, net		303,690	297,323
Capitalized interest	$ 2,765
OPAL Term Loan | Secured Debt
Property, Plant and Equipment [Line Items]
Capitalized interest		4,101	3,081
Plant and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		203,473	201,655
CNG/RNG fueling stations
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		46,892	34,567
Construction in progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		150,649	152,105
Buildings
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		2,585	2,585
Land
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		1,303	1,303
Service equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		2,207	1,888
Leasehold improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		815	815
Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		231	313
Office furniture and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		307	307
Computer software
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		277	277
Other
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		$ 571	$ 487

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Property, Plant, and Equipment, Net - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Depreciation	$ 3,485	$ 2,992	$ 10,162	$ 9,271

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Intangible Assets, Net - Schedule of Intangible Assets with Definite Lives (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Finite-Lived Intangible Assets [Line Items]
Cost	$ 10,642	$ 11,449
Accumulated Amortization	(8,942)	(9,282)
Intangible Assets, Net	1,700	2,167
Power purchase agreements
Finite-Lived Intangible Assets [Line Items]
Cost	8,999	8,999
Accumulated Amortization	(7,889)	(7,488)
Intangible Assets, Net	$ 1,110	$ 1,511
Weighted Average Amortization Period (Years)	18 years 1 month 6 days	18 years 1 month 6 days
Transmission/distribution interconnection
Finite-Lived Intangible Assets [Line Items]
Cost	$ 1,600	$ 1,600
Accumulated Amortization	(1,019)	(971)
Intangible Assets, Net	$ 581	$ 629
Weighted Average Amortization Period (Years)	15 years 1 month 6 days	15 years 1 month 6 days
CNG sales contract
Finite-Lived Intangible Assets [Line Items]
Cost		$ 807
Accumulated Amortization		(799)
Intangible Assets, Net		$ 8
Weighted Average Amortization Period (Years)		10 years
Intellectual property
Finite-Lived Intangible Assets [Line Items]
Cost	$ 43	$ 43
Accumulated Amortization	(34)	(24)
Intangible Assets, Net	$ 9	$ 19
Weighted Average Amortization Period (Years)	5 years	5 years

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Intangible Assets, Net - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Goodwill and Intangible Assets Disclosure [Abstract]
Amortization expense	$ 154	$ 197	$ 467	$ 595

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Intangible Assets, Net - Schedule of Estimated Future Amortization Expense For Definite Lived Intangible Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Goodwill and Intangible Assets Disclosure [Abstract]
For the remainder of the year ending December 31, 2023	$ 81
2024	267
2025	267
2026	239
2027	238
Thereafter	608
Intangible Assets, Net	$ 1,700	$ 2,167

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Goodwill (Details) $ in Thousands	Sep. 30, 2023 USD ($)
Goodwill [Roll Forward]
Goodwill, beginning balance	$ 54,608
Goodwill, ending balance	54,608
RNG Fuel
Goodwill [Roll Forward]
Goodwill, beginning balance	51,155
Goodwill, ending balance	51,155
Fuel Station Services
Goodwill [Roll Forward]
Goodwill, beginning balance	3,453
Goodwill, ending balance	$ 3,453

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Borrowings - Schedule of Borrowings (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Sep. 01, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Non-current borrowings total	$ 174,028		$ 88,312
Sunoma Loan
Debt Instrument [Line Items]
Long-term debt, gross	23,000		23,000
Less: unamortized debt issuance costs	(859)		(908)
Less: current portion	(1,739)		(380)
Non-current borrowings total	20,402		21,712
Convertible Note Payable
Debt Instrument [Line Items]
Long-term debt, gross	0		28,528
Less: current portion	0		(28,528)
Non-current borrowings total	0		0
Municipality Loan
Debt Instrument [Line Items]
Long-term debt, gross	0		76
Less: current portion	0		(76)
Non-current borrowings total	0		0
OPAL Term Loan | OPAL Term Loan
Debt Instrument [Line Items]
Long-term debt, gross	164,118	$ 87,602	96,090
Less: unamortized debt issuance costs	(10,492)		(1,758)
Less: current portion	0		(27,732)
Non-current borrowings total	153,626		66,600
OPAL Term Loan | Senior Secured Credit Facility, term loan | Senior Secured Credit Facility
Debt Instrument [Line Items]
Long-term debt, gross	0		15,250
Less: unamortized debt issuance costs	0		0
Less: current portion	0		(15,250)
Non-current borrowings total	0		0
Letter of Credit | Senior Secured Credit Facility, working capital facility | Senior Secured Credit Facility
Debt Instrument [Line Items]
Long-term debt, gross	0		7,500
Less: current portion	0		(7,500)
Non-current borrowings total	$ 0		$ 0

XML

Borrowings - Schedule of Principal Maturities of Debt (Details) $ in Thousands	Sep. 30, 2023 USD ($)
Debt Instrument [Line Items]
For the remainder of the year ending December 31, 2023	$ 533
2024	1,620
2025	16,527
2026	21,592
2027	146,846
Total	187,118
OPAL Term Loan | OPAL Term Loan
Debt Instrument [Line Items]
For the remainder of the year ending December 31, 2023	0
2024	0
2025	14,771
2026	19,694
2027	129,653
Total	164,118
Sunoma Loan
Debt Instrument [Line Items]
For the remainder of the year ending December 31, 2023	533
2024	1,620
2025	1,756
2026	1,898
2027	17,193
Total	$ 23,000

XML

Borrowings - Narrative (Details) - USD ($) $ in Thousands								1 Months Ended	3 Months Ended				9 Months Ended
	Sep. 01, 2023	May 30, 2023	Dec. 19, 2022	Aug. 04, 2022	Jul. 19, 2022	Aug. 27, 2020	Sep. 21, 2015	Jul. 31, 2022	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022	Oct. 22, 2021	May 01, 2021
Debt Instrument [Line Items]
Repayments on lines of credit													$ 22,750	$ 3,674
Cash dividends received									$ 126			$ 126	126	126
Paid-in-kind preferred dividend										$ 458	$ 445	310
Loss on debt extinguishment									953			$ 0	2,848	0
Change in fair value of Convertible note payable													(1,579)	$ 151
Loan outstanding									187,118				187,118
Related Party
Debt Instrument [Line Items]
Dividends receivable									$ 489				$ 489		$ 489
Senior Secured Credit Facility
Debt Instrument [Line Items]
Aggregate principal amount							$ 150,000
Repayments on lines of credit							$ 14,300
Weighed average effective interest rate									5.60%			6.80%	5.60%	5.40%
Senior Secured Credit Facility | Secured Overnight Financing Rate (SOFR) | Variable Rate, Fixed Margin, Period One
Debt Instrument [Line Items]
Basis spread							2.75%
Senior Secured Credit Facility | Secured Overnight Financing Rate (SOFR) | Variable Rate, Fixed Margin, Period Two
Debt Instrument [Line Items]
Basis spread							3.00%
Senior Secured Credit Facility | Secured Overnight Financing Rate (SOFR) | Variable Rate, Fixed Margin, Period Three
Debt Instrument [Line Items]
Basis spread							3.25%
Senior Secured Credit Facility | Senior Secured Credit Facility - Debt Reserve And Liquidity Facility
Debt Instrument [Line Items]
Aggregate principal amount							$ 6,000
Senior Secured Credit Facility | Secured Debt | Senior Secured Credit Facility, term loan
Debt Instrument [Line Items]
Aggregate principal amount							125,000
Debt outstanding									$ 0				$ 0		15,250
Senior Secured Credit Facility | Secured Debt | Omnibus and Consent Agreement (the “FM3 Amendment”)
Debt Instrument [Line Items]
Repayments on lines of credit			$ 54,929
Senior Secured Credit Facility | Letter of Credit | Senior Secured Credit Facility, working capital facility
Debt Instrument [Line Items]
Revolving credit arrangement borrowing capacity							$ 19,000
Debt outstanding									0				0		7,500
Secured Debt | OPAL Term Loan
Debt Instrument [Line Items]
Aggregate principal amount																$ 125,000
Debt outstanding	$ 87,602								164,118				164,118		96,090
Loss on debt extinguishment									953				953
Third party legal costs									295				295
Loan outstanding									$ 164,118				$ 164,118
Weighed average effective interest rate									9.20%			6.40%	8.00%	5.20%
Secured Debt | Opal Term Loan II
Debt Instrument [Line Items]
Financing fees paid				$ 2,200
Loss on debt extinguishment													$ 1,895
Third party fees				1,376
Loan outstanding		$ 0
Secured Debt | Opal Term Loan II | Paragon
Debt Instrument [Line Items]
Transaction costs reimbursed		$ 826
Secured Debt | Opal Term Loan II, Delayed Term Loan Facility ("DDTL")
Debt Instrument [Line Items]
Aggregate principal amount				$ 100,000
Term of loan (in years)				2 years
Secured Debt | Opal Term Loan II, Debt Service Reserve ("DSR") Facility
Debt Instrument [Line Items]
Aggregate principal amount				$ 5,000
Line of Credit | Secured Debt | Opal Credit Agreement
Debt Instrument [Line Items]
Aggregate principal amount	450,000
Repayments on lines of credit	$ 87,602
Term of loan (in years)	18 months
Draws on line of credit	$ 144,118								$ 20,000
Amortization rate	1.00%
Minimum required debt service coverage ratio	1.2
Minimum consolidated debt to cash flow ratio during the delayed draw availability period	4.5
Minimum consolidated debt to cash flow ratio after the delayed draw availability period	4.0
Line of Credit | Secured Debt | Opal Credit Agreement | Redeemable Preferred non-controlling interests
Debt Instrument [Line Items]
Paid-in-kind preferred dividend	$ 15,669
Line of Credit | Secured Debt | Opal Credit Agreement | Minimum
Debt Instrument [Line Items]
Leverage based cash sweep	25.00%
Line of Credit | Secured Debt | Opal Credit Agreement | Maximum
Debt Instrument [Line Items]
Leverage based cash sweep	100.00%
Line of Credit | Secured Debt | Opal Credit Agreement | Term Secured Overnight Financing Rate (SOFR) | Variable Rate, Fixed Margin, Period One
Debt Instrument [Line Items]
Basis spread	3.50%
Line of Credit | Secured Debt | Opal Credit Agreement | Term Secured Overnight Financing Rate (SOFR) | Variable Rate, Fixed Margin, Period Two
Debt Instrument [Line Items]
Basis spread	0.25%
Line of Credit | Revolving Credit Facility | Opal Credit Agreement
Debt Instrument [Line Items]
Revolving credit arrangement borrowing capacity	$ 50,000
Convertible Note Payable
Debt Instrument [Line Items]
Aggregate principal amount																	$ 50,000
Debt outstanding									$ 0				$ 0		28,528
Payments on indebtedness of Convertible Note Payable	30,107
Interest rate on loan									8.00%			8.00%	8.00%	8.00%			8.00%
Percentage of notes converted								50.00%
Redeemed outstanding debt								$ 30,595
Change in fair value of Convertible note payable									$ (436)			$ 2,261	$ (1,579)	$ 151
Convertible Note Payable | Class A common stock
Debt Instrument [Line Items]
Shares issued upon conversion (in shares)								3,059,533
Letter of Credit | Revolving Credit Facility | Opal Credit Agreement
Debt Instrument [Line Items]
Revolving credit arrangement borrowing capacity	9,000
Financing fees paid	$ 10,790
Sunoma Loan
Debt Instrument [Line Items]
Aggregate principal amount						$ 20,000
Debt outstanding									23,000				23,000		23,000
Minimum required debt service coverage ratio						1.25
Maximum debt to worth ratio						5
Minimum current ratio						1.0
Loan outstanding									$ 23,000				$ 23,000
Interest rate during period									8.00%			7.81%	8.00%	9.00%
Sunoma Loan | Minimum
Debt Instrument [Line Items]
Effective interest rate						7.75%
Sunoma Loan | Sunoma
Debt Instrument [Line Items]
Financing fees paid						$ 635
Sunoma Loan | Prime Rate
Debt Instrument [Line Items]
Basis spread						3.50%
Permanent Loan
Debt Instrument [Line Items]
Aggregate principal amount					$ 23,000
Interest rate on loan					7.68%
Payment of quarterly amortization					$ 533
Municipality Loan
Debt Instrument [Line Items]
Debt outstanding									$ 0				$ 0		$ 76
Interest rate on loan									3.00%				3.00%
Payments													$ 1,600
Weighed average effective interest rate												3.00%		3.00%

XML

Borrowings - Schedule of Interest Expense on Borrowings (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Debt Instrument [Line Items]
Convertible Note Payable mark-to-market			$ (1,579)	$ 151
Commitment fees and other finance fees	$ (248)	$ (401)	(560)	(605)
Amortization of deferred financing cost	(652)	(616)	(1,447)	(1,514)
Interest expense on finance leases	(24)	(15)	(61)	(28)
Interest income	563	613	2,448	1,512
Total interest expense	(2,885)	(790)	(4,482)	(7,212)
Interest capitalized	842		4,627	0
Senior Secured Credit Facility
Debt Instrument [Line Items]
Interest expense	0	(1,101)	(282)	(2,543)
Convertible Note Payable mark-to-market
Debt Instrument [Line Items]
Convertible Note Payable mark-to-market	(436)	2,261	(1,579)	151
Sunoma Loan
Debt Instrument [Line Items]
Interest expense	(454)	(424)	(1,348)	(1,335)
OPAL Term Loan
Debt Instrument [Line Items]
Interest expense	$ (1,634)	$ (1,107)	$ (1,653)	$ (2,850)

XML

Leases - Narrative (Details) $ in Thousands			3 Months Ended		9 Months Ended		12 Months Ended
	Feb. 02, 2025 USD ($)	Jul. 05, 2023 USD ($)	Sep. 30, 2023 USD ($) facility vehicle agreement lease	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) facility vehicle agreement lease	Sep. 30, 2022 USD ($)	Feb. 01, 2025 USD ($)	Feb. 01, 2024 USD ($)	Feb. 01, 2023 USD ($)	Dec. 31, 2022 USD ($)	Jan. 01, 2022 agreement
Operating Leased Assets [Line Items]
Total revenues			$ 71,101	$ 66,550	$ 169,100	$ 168,814
Operating right-of-use assets			$ 12,368		12,368					$ 11,744
Increase in operating lease liability					$ (435)	(518)
Number of vehicles | vehicle			65		65
RNG Fuel
Operating Leased Assets [Line Items]
Number of facilities | facility			2		2
Fuel Station Services
Operating Leased Assets [Line Items]
Total revenues			$ 37,305	35,771	$ 88,089	87,376
Renewable Power
Operating Leased Assets [Line Items]
Total revenues			$ 13,708	12,486	$ 43,543	32,623
Power purchase agreements
Operating Leased Assets [Line Items]
Number of agreements | agreement			2		2						2
Power purchase agreements | Renewable Power
Operating Leased Assets [Line Items]
Total revenues			$ 223	384	$ 818	1,014
Fuel Provider Agreements ("FPAs") | Fuel Station Services
Operating Leased Assets [Line Items]
Total revenues			$ 917	$ 856	$ 2,119	$ 1,906
Minimum
Operating Leased Assets [Line Items]
Incremental borrowing rate			2.30%		2.30%
Maximum
Operating Leased Assets [Line Items]
Incremental borrowing rate			8.44%		8.44%
Site leases
Operating Leased Assets [Line Items]
Operating right-of-use assets			$ 11,287		$ 11,287					10,338
Lease liability, operating lease			$ 11,294		$ 11,294
Incremental borrowing rate			5.40%		5.40%
Number of leases | lease			3		3
Site leases | Beacon
Operating Leased Assets [Line Items]
Term of lease			20 years		20 years
Monthly rental payments					$ 11
Site leases | MS Digester ("MS") And VS Digester ("VS")
Operating Leased Assets [Line Items]
Term of lease			20 years		20 years
Quarterly rent payments					$ 125
Incremental borrowing rate			8.44%		8.44%
Additional renewal term (in years)			10 months		10 months
Increase in right of use asset					$ 280
Increase in operating lease liability					$ 280
Site leases | RNG Fuel
Operating Leased Assets [Line Items]
Number of facilities | facility					3
Term of lease		20 years
Quarterly rent payments		$ 21,250
Percentage escalator		5.00%
Anniversary of rent increase (in years)		5 years
Operating right-of-use assets			$ 798		$ 798
Lease liability, operating lease			$ 798		$ 798
Incremental borrowing rate			8.44%		8.44%
Office leases
Operating Leased Assets [Line Items]
Term of lease			36 months		36 months
Monthly rental payments					$ 26				$ 27
Operating right-of-use assets			$ 1,081		1,081					$ 1,406
Lease liability, operating lease			$ 1,230		$ 1,230
Incremental borrowing rate			2.30%		2.30%
Additional renewal term (in years)			24 months		24 months
Number of leases | lease			1		1
Office leases | Subsequent Event | Forecast
Operating Leased Assets [Line Items]
Monthly rental payments	$ 46						$ 45	$ 43

XML

Leases - Right-of-Use Assets and Lease Liabilities (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Accrued expenses and other current liabilities (includes $602 and $646 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)		Accrued expenses and other current liabilities (includes $602 and $646 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)		Accrued expenses and other current liabilities (includes $602 and $646 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Property, plant, and equipment, net (includes $26,684 and $73,140 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)		Property, plant, and equipment, net (includes $26,684 and $73,140 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)		Property, plant, and equipment, net (includes $26,684 and $73,140 at September 30, 2023 and December 31, 2022, respectively, related to consolidated VIEs)
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other long-term liabilities		Other long-term liabilities		Other long-term liabilities
Operating leases, Right-of-use assets	$ 12,368		$ 12,368		$ 11,744
Vehicles leases	1,708		1,708		1,236
Operating lease right-of-use assets	14,076		14,076		12,980
Operating lease liabilities - current portion	625		625		630
Lease liabilities - current portion, finance lease	577		577		449
Lease liabilities - current portion	1,202		1,202		1,079
Operating lease liabilities - non-current portion	11,899		11,899		11,245
Lease liabilities - non-current portion, finance lease	1,131		1,131		825
Lease liabilities - non-current portion	13,030		13,030		12,070
Amortization of right-of-use assets - finance leases	155	$ 81	436	$ 245
Interest expense on lease liabilities - finance leases	24	15	61	28
Total lease expense	$ 563	478	$ 1,649	1,421
Weighted average remaining lease term (years)
Operating leases	19 years 1 month 6 days		19 years 1 month 6 days
Financing leases	3 years 1 month 6 days		3 years 1 month 6 days
Weighted average discount rate
Operating leases	7.84%		7.84%
Financing leases	6.39%		6.39%
Minimum
Lessee, Lease, Description [Line Items]
Discount rate for operating leases	2.30%		2.30%
Maximum
Lessee, Lease, Description [Line Items]
Discount rate for operating leases	8.44%		8.44%
Site leases
Lessee, Lease, Description [Line Items]
Operating leases, Right-of-use assets	$ 11,287		$ 11,287		10,338
Operating lease liabilities - current portion	126		126		181
Operating lease liabilities - non-current portion	$ 11,168		$ 11,168		10,135
Discount rate for operating leases	5.40%		5.40%
Lease expense	$ 263	261	$ 789	785
Office leases
Lessee, Lease, Description [Line Items]
Operating leases, Right-of-use assets	1,081		1,081		1,406
Operating lease liabilities - current portion	499		499		449
Operating lease liabilities - non-current portion	$ 731		$ 731		$ 1,110
Discount rate for operating leases	2.30%		2.30%
Lease expense	$ 121	$ 121	$ 363	$ 363

XML

Leases - Future Minimum Lease Payments (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Discount rate upon adoption, finance lease	7.60%
2023, finance lease	$ 147
2023	538
2024, finance lease	667
2024	2,265
2025, finance lease	561
2025	2,252
2026, finance lease	406
2026	1,582
2027 and beyond, finance lease	115
2027 and beyond	20,260
Future minimum lease payments, finance lease	1,896
Future minimum lease payments	26,897
Lease liabilities, finance lease	1,708
Lease liabilities	14,232
Operating lease liabilities - current portion	625	$ 630
Lease liabilities - current portion, finance lease	577	449
Lease liabilities - current portion	1,202	1,079
Operating lease liabilities - non-current portion	11,899	11,245
Lease liabilities - non-current portion, finance lease	1,131	825
Lease liabilities - non-current portion	13,030	12,070
Discount based on incremental borrowing rate, finance lease	188
Discount based on incremental borrowing rate	$ 12,665
Site leases
Lessee, Lease, Description [Line Items]
Discount rate upon adoption, operating lease	5.40%
2023, operating lease	$ 261
2024, operating lease	1,058
2025, operating lease	1,129
2026, operating lease	1,129
2027 and beyond, operating lease	20,145
Future minimum lease payments, operating lease	23,722
Lease liabilities, operating lease	11,294
Operating lease liabilities - current portion	126	181
Operating lease liabilities - non-current portion	11,168	10,135
Discount based on incremental borrowing rate, operating lease	$ 12,428
Office leases
Lessee, Lease, Description [Line Items]
Discount rate upon adoption, operating lease	2.30%
2023, operating lease	$ 130
2024, operating lease	540
2025, operating lease	562
2026, operating lease	47
2027 and beyond, operating lease	0
Future minimum lease payments, operating lease	1,279
Lease liabilities, operating lease	1,230
Operating lease liabilities - current portion	499	449
Operating lease liabilities - non-current portion	731	$ 1,110
Discount based on incremental borrowing rate, operating lease	$ 49

XML

Derivative Financial Instruments and Fair Value Measurements - Narrative (Details) $ in Thousands		1 Months Ended	3 Months Ended		9 Months Ended
	May 30, 2023 USD ($) interest_rate_swap	Dec. 31, 2018 MWh	Sep. 30, 2023 USD ($) $ / shares yr commodity_swap	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) $ / shares yr commodity_swap	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($) commodity_swap	Aug. 31, 2022 USD ($) interest_rate_swap	Aug. 16, 2022 USD ($)	Nov. 30, 2019 uSD_per_Megawatt-Hour
Derivative [Line Items]
Gain on settlement			$ (138)	$ (1,908)	$ 4,955	$ (1,580)
Proceeds from settlement from counterparty					136
Loss on termination					46
Effective portion of the the cash flow hedge attributable to equity method investments			406	$ 0	515	$ 0
Long-term debt, excluding current portion			$ 174,028		$ 174,028		$ 88,312
Sponsor Earnout Awards
Derivative [Line Items]
Warrants expiration period			4 years		4 years
OPAL Earnout Awards
Derivative [Line Items]
Warrants expiration period			2 years		2 years
Level 2
Derivative [Line Items]
Long-term debt, excluding current portion			$ 174,028		$ 174,028		88,312
Share price | Sponsor Earnout Awards
Derivative [Line Items]
Warrants, measurement input | $ / shares			8.20		8.20
Share price | OPAL Earnout Awards
Derivative [Line Items]
Warrants, measurement input | $ / shares			8.20		8.20
Expected volatility | Sponsor Earnout Awards
Derivative [Line Items]
Warrants, measurement input			0.55		0.55
Expected volatility | OPAL Earnout Awards
Derivative [Line Items]
Warrants, measurement input			0.50		0.50
Risk free interest rate | Sponsor Earnout Awards
Derivative [Line Items]
Warrants, measurement input			0.0472		0.0472
Risk free interest rate | OPAL Earnout Awards
Derivative [Line Items]
Warrants, measurement input			0.055		0.055
Expected term | Sponsor Earnout Awards
Derivative [Line Items]
Warrants, measurement input | yr			3.8		3.8
Expected term | OPAL Earnout Awards
Derivative [Line Items]
Warrants, measurement input | yr			1.5		1.5
Dividend yield | Sponsor Earnout Awards
Derivative [Line Items]
Warrants, measurement input			0		0
Dividend yield | OPAL Earnout Awards
Derivative [Line Items]
Warrants, measurement input			0		0
Weighted average cost of capital | OPAL Earnout Awards
Derivative [Line Items]
Warrants, measurement input			0.16		0.16
Minimum | Discount rate | Level 3
Derivative [Line Items]
Asset retirement obligation, measurement input			0.0575		0.0575
Maximum | Discount rate | Level 3
Derivative [Line Items]
Asset retirement obligation, measurement input			0.085		0.085
Interest Rate Swap
Derivative [Line Items]
Number of derivative instruments held | interest_rate_swap	2							2
Notional Amount			$ 0		$ 0		$ 61,926	$ 61,926
Fixed rate								2.47%
Gain on settlement	$ 812
Interest Rate Swap | Paragon
Derivative [Line Items]
Number of derivative instruments held | interest_rate_swap	4
Notional Amount	$ 56,914
Fixed rate	3.52%
Gain on settlement					$ 812
Interest Rate Swap | Cash Flow Hedging
Derivative [Line Items]
Number of derivative instruments held | interest_rate_swap								2
Interest rate swaption
Derivative [Line Items]
Notional Amount									$ 13,074
Fixed rate									2.32%
Commodity swap contracts
Derivative [Line Items]
Number of derivative instruments held | commodity_swap			3		3		3
Minimum output (in MWh per year) | MWh		34,554
Commodity swap contracts | Minimum
Derivative [Line Items]
Average Contract Price (per MWh) | uSD_per_Megawatt-Hour										35.75
Commodity swap contracts | Maximum
Derivative [Line Items]
Average Contract Price (per MWh) | uSD_per_Megawatt-Hour										51.25

XML

Derivative Financial Instruments and Fair Value Measurements - Interest Rate Swaps (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022	Aug. 31, 2022
Interest Rate Swap
Derivative [Line Items]
Fixed rate			2.47%
Notional Amount	$ 0	$ 61,926	$ 61,926
Interest rate swap 1
Derivative [Line Items]
Fixed rate	2.47%
Notional Amount	$ 0	41,284
Interest rate swap 2
Derivative [Line Items]
Fixed rate	2.47%
Notional Amount	$ 0	$ 20,642

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Derivative Financial Instruments and Fair Value Measurements - Derivatives Fair Values on Balance Sheet (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Derivatives, Fair Value [Line Items]
Derivative assets (liabilities)	$ 0	$ 1,136
Swaption | Derivatives designated as economic hedges:
Derivatives, Fair Value [Line Items]
Derivative assets	0	182
Interest Rate Swap | Derivatives designated as cash flow hedges:
Derivatives, Fair Value [Line Items]
Derivative assets	$ 0	$ 954

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Derivative Financial Instruments and Fair Value Measurements - Effect of Derivative Instruments on Statement of Operations (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Net periodic settlements	$ 0	$ (1,631)	$ 812	$ (677)
Change in fair value of derivative instruments, net	0	195	766	523
Derivatives designated as economic hedges:
Derivative Instruments, Gain (Loss) [Line Items]
Commodity swaps - realized (loss) gain	493	(744)	1,373	(931)
Commodity swaps - unrealized gain (loss)	(30)	161	733	(775)
Interest rate swaps
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate swaps	0	1,580	0	954
Swaption
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate swaps	0	246	(46)	246
Commodity swap contracts | Derivatives designated as economic hedges:
Derivative Instruments, Gain (Loss) [Line Items]
Change in fair value of derivative instruments, net	$ 463	$ (583)	$ 2,106	$ (1,706)

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Derivative Financial Instruments and Fair Value Measurements - Fair Value of Derivative Instruments on Balance Sheet and Effect of Netting Arrangements (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Derivative [Line Items]
Gross Amounts of Recognized Assets	$ 0	$ 1,136
Gross Amounts Offset in the Balance Sheet	0	0
Net Amounts of Assets in the Balance Sheet	0	1,136
Derivative financial assets, current portion	486	182
Derivative financial assets, non-current portion	117	954
Derivative financial liability, current portion	0	(4,596)
Interest rate swap asset
Derivative [Line Items]
Gross Amounts of Recognized Assets	0	954
Gross Amounts Offset in the Balance Sheet	0	0
Net Amounts of Assets in the Balance Sheet	0	954
Swaption asset
Derivative [Line Items]
Gross Amounts of Recognized Assets	0	182
Gross Amounts Offset in the Balance Sheet	0	0
Net Amounts of Assets in the Balance Sheet	0	182
Commodity swap contracts | Derivatives designated as economic hedges:
Derivative [Line Items]
Derivative financial assets, current portion	486	0
Derivative financial assets, non-current portion	117	0
Derivative financial liability, current portion	$ 0	$ (130)

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Derivative Financial Instruments and Fair Value Measurements - Summary of Commodity Swaps (Details)	24 Months Ended
	Dec. 31, 2024 MWh	Nov. 17, 2022 uSD_per_Megawatt-Hour	Oct. 17, 2022 uSD_per_Megawatt-Hour
Commodity Contract, Contract One
Derivative [Line Items]
Average Contract Price (per MWh) | uSD_per_Megawatt-Hour			68.50
Commodity Contract, Contract One | Forecast
Derivative [Line Items]
Notional Quantity per Year (“MWh”) | MWh	70,176
Commodity Contract, Contract Two
Derivative [Line Items]
Average Contract Price (per MWh) | uSD_per_Megawatt-Hour			65.50
Commodity Contract, Contract Two | Forecast
Derivative [Line Items]
Notional Quantity per Year (“MWh”) | MWh	26,280
Commodity Contract, Contract Three
Derivative [Line Items]
Average Contract Price (per MWh) | uSD_per_Megawatt-Hour		81.50
Commodity Contract, Contract Three | Forecast
Derivative [Line Items]
Notional Quantity per Year (“MWh”) | MWh	35,088

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Derivative Financial Instruments and Fair Value Measurements - Other Derivative Liabilities (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Derivative [Line Items]
Change in fair value of derivative instruments, net	$ 0	$ 195	$ 766	$ 523
Other Derivatives
Derivative [Line Items]
Change in fair value of derivative instruments, net	(138)	(2,103)	4,189	(2,103)
Put option to Meteora
Derivative [Line Items]
Change in fair value of derivative instruments, net	0	384	(311)	384
Sponsor Earnout Awards
Derivative [Line Items]
Change in fair value of derivative instruments, net	(338)	1,100	(201)	1,100
OPAL Earnout Awards
Derivative [Line Items]
Change in fair value of derivative instruments, net	200	5,300	4,701	5,300
Public Warrants
Derivative [Line Items]
Change in fair value of derivative instruments, net	0	(3,578)	0	(3,578)
Private Warrants
Derivative [Line Items]
Change in fair value of derivative instruments, net	$ 0	$ (5,309)	$ 0	$ (5,309)

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Derivative Financial Instruments and Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Liabilities:
Asset retirement obligation	$ 6,563	$ 6,256
Fair Value, Recurring
Liabilities:
Asset retirement obligation	6,563	6,256
Convertible Not Payable		28,528
Earnout liabilities	4,291	8,790
Assets:
Short term investments	18,028	64,976
Fair Value, Recurring | Put option with Meteora
Liabilities:
Derivative liabilities		4,466
Fair Value, Recurring | Commodity swap contracts
Liabilities:
Derivative liabilities		130
Assets:
Derivative assets	603	954
Fair Value, Recurring | Swaption asset
Assets:
Derivative assets		182
Fair Value, Recurring | Level 1
Liabilities:
Asset retirement obligation	0	0
Convertible Not Payable		0
Earnout liabilities	0	0
Assets:
Short term investments	18,028	64,976
Fair Value, Recurring | Level 1 | Put option with Meteora
Liabilities:
Derivative liabilities		0
Fair Value, Recurring | Level 1 | Commodity swap contracts
Liabilities:
Derivative liabilities		0
Assets:
Derivative assets	0	0
Fair Value, Recurring | Level 1 | Swaption asset
Assets:
Derivative assets		0
Fair Value, Recurring | Level 2
Liabilities:
Asset retirement obligation	0	0
Convertible Not Payable		28,528
Earnout liabilities	0	0
Assets:
Short term investments	0	0
Fair Value, Recurring | Level 2 | Put option with Meteora
Liabilities:
Derivative liabilities		0
Fair Value, Recurring | Level 2 | Commodity swap contracts
Liabilities:
Derivative liabilities		130
Assets:
Derivative assets	603	954
Fair Value, Recurring | Level 2 | Swaption asset
Assets:
Derivative assets		182
Fair Value, Recurring | Level 3
Liabilities:
Asset retirement obligation	6,563	6,256
Convertible Not Payable
Earnout liabilities	4,291	8,790
Assets:
Short term investments	0	0
Fair Value, Recurring | Level 3 | Put option with Meteora
Liabilities:
Derivative liabilities		4,466
Fair Value, Recurring | Level 3 | Commodity swap contracts
Liabilities:
Derivative liabilities		0
Assets:
Derivative assets	$ 0	0
Fair Value, Recurring | Level 3 | Swaption asset
Assets:
Derivative assets		$ 0

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Related Parties - Narrative (Details) $ in Thousands			1 Months Ended	3 Months Ended		8 Months Ended	9 Months Ended		12 Months Ended
	Nov. 29, 2021 USD ($) subsidiary shares	Dec. 31, 2020 USD ($)	Aug. 31, 2021 USD ($) shares	Sep. 30, 2023 USD ($) commodity_swap	Sep. 30, 2022 USD ($)	Mar. 31, 2021	Sep. 30, 2023 USD ($) commodity_swap	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($) commodity_swap shares
Related Party Transaction [Line Items]
Paid-in-kind dividends issued and outstanding units				$ 2,126	$ 2,045		$ 6,408	$ 3,273
Stock subscribed (in shares) | shares	1,000,000
Amount sold									$ 100,000
Stock issued (in shares) | shares									1,000,000
Total revenues				71,101	66,550		169,100	168,814
Net income (loss) from equity method investments				$ 1,726	3,694		$ 1,433	3,658
Commodity swap contracts
Related Party Transaction [Line Items]
Number of derivative instruments held | commodity_swap				3			3		3
Renewable Power
Related Party Transaction [Line Items]
Total revenues				$ 13,708	12,486		$ 43,543	32,623
Reynolds
Related Party Transaction [Line Items]
Percentage of ownership interest acquired			100.00%
Cash payments			$ 12,020
Related Party
Related Party Transaction [Line Items]
Accounts payable				1,365			1,365		$ 1,346
Related Party | Renewable Power
Related Party Transaction [Line Items]
Total revenues				1,732	927		5,006	3,196
Related Party | Hillman
Related Party Transaction [Line Items]
Common units, shares issued (in shares) | shares	14
Total consideration from related parties	$ 30,000
Related Party | Reynolds | GREP
Related Party Transaction [Line Items]
Cash consideration			$ 1,570
Related Party | Pine Bend, Sunoma And Noble Road | Environmental Processing Fees
Related Party Transaction [Line Items]
Total revenues				$ 570	80		$ 1,711	322
Term of related party contract (in years)						10 years
Parent Company | Fortistar | Administrative Services Agreement
Related Party Transaction [Line Items]
Service fees per year		$ 580
GREP
Related Party Transaction [Line Items]
Percentage of ownership			20.00%	20.00%			20.00%
Net income (loss) from equity method investments				$ (374)	3,034		$ (810)	2,478
GREP | BioTown Biogas LLC (“Biotown”)
Related Party Transaction [Line Items]
Percentage of ownership			50.00%
RNG Fuel | NextEra
Related Party Transaction [Line Items]
Minimum of environmental attributes to be sold, percentage	90.00%
RNG Fuel | Related Party | NextEra
Related Party Transaction [Line Items]
Minimum of environmental attributes to be sold, percentage	90.00%
RNG Fuel | Hillman | Related Party
Related Party Transaction [Line Items]
Number of noncontrolling interests in renewable natural gas project subsidiaries | subsidiary	4
Natural Gas, Renewable And Fuel Station Services | Related Party | NextEra
Related Party Transaction [Line Items]
Total revenues				25,724	19,336		43,784	49,024
Series A-1 preferred units | Related Party | Hillman
Related Party Transaction [Line Items]
Preferred units, shares issued (in shares) | shares	300,000
Paid-in-kind dividends issued and outstanding units				$ 656	$ 613		$ 1,986	$ 1,820
Class B common stock | Related Party | Reynolds | GREP
Related Party Transaction [Line Items]
Equity investment held (in shares) | shares			1,570

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Related Parties - Fees Upon Entering Into Management Services Agreement with Related Party (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Related Party Transaction [Line Items]
Selling, general, and administrative	$ 13,594	$ 15,751	$ 41,729	$ 34,561
Related Party | Costar
Related Party Transaction [Line Items]
Selling, general, and administrative	1,334	1,382	4,110	3,846
Related Party | Costar | Staffing and management services
Related Party Transaction [Line Items]
Selling, general, and administrative	414	578	1,406	1,683
Related Party | Costar | Rent - fixed compensation
Related Party Transaction [Line Items]
Selling, general, and administrative	166	168	494	442
Related Party | Costar | IT services
Related Party Transaction [Line Items]
Selling, general, and administrative	$ 754	$ 636	$ 2,210	$ 1,721

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Reportable Segments and Geographic Information - Narrative (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) segment	Sep. 30, 2022 USD ($)
Segment Reporting [Abstract]
Number of operating segments | segment			4
Number of reportable segments | segment			4
Reclassification [Line Items]
Total revenues	$ 71,101	$ 66,550	$ 169,100	$ 168,814
RNG Fuel
Reclassification [Line Items]
Total revenues	20,088	18,293	37,468	48,815
Cost of sales	8,896	10,872	24,303	27,043
RNG Fuel | Revision of Prior Period, Reclassification, Adjustment
Reclassification [Line Items]
Total revenues	(16,852)	(12,545)	(35,103)	(31,852)
Cost of sales	(11,703)	(10,088)	(28,527)	(24,801)
Fuel Station Services
Reclassification [Line Items]
Total revenues	37,305	35,771	88,089	87,376
Cost of sales	31,887	30,837	79,655	74,130
Fuel Station Services | Revision of Prior Period, Reclassification, Adjustment
Reclassification [Line Items]
Total revenues	16,852	12,545	35,103	31,852
Cost of sales	11,703	10,088	28,527	24,801
Renewable Power
Reclassification [Line Items]
Total revenues	13,708	12,486	43,543	32,623
Cost of sales	11,112	7,645	28,251	23,593
Renewable Power | Revision of Prior Period, Reclassification, Adjustment
Reclassification [Line Items]
Total revenues	4,539	1,543	15,783	2,528
Renewable Power | Revision of Prior Period, Reclassification, Adjustment | Environmental attributes
Reclassification [Line Items]
Total revenues	$ (4,539)	$ (1,543)	$ (15,783)	$ (2,528)

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Reportable Segments and Geographic Information - Schedule of Total Revenues by Segment (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Revenues:
Revenues:	$ (71,101)	$ (66,550)	$ (169,100)	$ (168,814)
Equity Method Investment(s)
Revenues:
Revenues:	(9,463)	(42,158)	(23,927)	(47,247)
Intersegment
Revenues:
Revenues:	3,021	3,150	10,967	8,172
Renewable Power
Revenues:
Revenues:	(13,708)	(12,486)	(43,543)	(32,623)
Renewable Power | Operating Segments
Revenues:
Revenues:	(13,708)	(49,737)	(43,543)	(70,937)
RNG Fuel
Revenues:
Revenues:	(20,088)	(18,293)	(37,468)	(48,815)
RNG Fuel | Operating Segments
Revenues:
Revenues:	(29,551)	(22,788)	(61,395)	(61,971)
Fuel Station Services
Revenues:
Revenues:	(37,305)	(35,771)	(88,089)	(87,376)
Fuel Station Services | Operating Segments
Revenues:
Revenues:	$ (40,326)	$ (39,333)	$ (99,056)	$ (91,325)

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Reportable Segments and Geographic Information - Schedule of Interest Expense on Borrowings (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Segment Reporting Information [Line Items]
Interest and Financing Expense, Net:	$ (2,885)	$ (790)	$ (4,482)	$ (7,212)
Renewable Power | Operating Segments
Segment Reporting Information [Line Items]
Interest and Financing Expense, Net:	(2)	(1,440)	(260)	(3,559)
RNG Fuel | Operating Segments
Segment Reporting Information [Line Items]
Interest and Financing Expense, Net:	(3,243)	(189)	(4,616)	(240)
Fuel Station Services | Operating Segments
Segment Reporting Information [Line Items]
Interest and Financing Expense, Net:	27	(14)	120	(28)
Corporate | Operating Segments
Segment Reporting Information [Line Items]
Interest and Financing Expense, Net:	$ 333	$ 853	$ 274	$ (3,385)

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Reportable Segments and Geographic Information - Schedule of Depreciation, Amortization and Accretion (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Segment Reporting Information [Line Items]
Depreciation, Amortization, and Accretion:	$ 3,739	$ 3,380	$ 10,934	$ 10,101
Equity Method Investment(s)
Segment Reporting Information [Line Items]
Depreciation, Amortization, and Accretion:	(1,167)	(699)	(2,854)	(1,272)
Other
Segment Reporting Information [Line Items]
Depreciation, Amortization, and Accretion:	9	31	36	95
Renewable Power | Operating Segments
Segment Reporting Information [Line Items]
Depreciation, Amortization, and Accretion:	1,488	1,176	4,389	4,283
RNG Fuel | Operating Segments
Segment Reporting Information [Line Items]
Depreciation, Amortization, and Accretion:	2,492	2,461	6,808	6,379
Fuel Station Services | Operating Segments
Segment Reporting Information [Line Items]
Depreciation, Amortization, and Accretion:	$ 917	$ 411	$ 2,555	$ 616

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Reportable Segments and Geographic Information - Schedule of Net Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income	$ 227	$ 5,369	$ 106,931	$ 560
Equity Method Investment(s)	1,726	3,694	1,433	3,658
Renewable Power | Operating Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income	983	3,483	10,584	1,314
RNG Fuel | Operating Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income	10,821	5,669	8,044	21,775
Fuel Station Services | Operating Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income	5,530	11,624	7,429	12,574
Corporate | Operating Segments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income	$ (18,833)	$ (19,101)	$ 79,441	$ (38,761)

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Reportable Segments and Geographic Information - Schedule of Cash Paid for Purchases of Property, Plant and Equipment (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Segment Reporting Information [Line Items]
Cash paid for Purchases of Property, Plant, and Equipment:	$ 92,250	$ 85,334
Operating Segments | Renewable Power
Segment Reporting Information [Line Items]
Cash paid for Purchases of Property, Plant, and Equipment:	0	1,800
Operating Segments | Fuel Station Services
Segment Reporting Information [Line Items]
Cash paid for Purchases of Property, Plant, and Equipment:	16,860	7,038
Operating Segments | RNG Fuel
Segment Reporting Information [Line Items]
Cash paid for Purchases of Property, Plant, and Equipment:	$ 75,390	$ 76,496

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Reportable Segments and Geographic Information - Total Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Segment Reporting, Asset Reconciling Item [Line Items]
Total Assets:	$ 690,455	$ 644,856
Equity Method Investment(s)	199,466	51,765
Operating Segments | Renewable Power
Segment Reporting, Asset Reconciling Item [Line Items]
Total Assets:	39,503	43,468
Operating Segments | RNG Fuel
Segment Reporting, Asset Reconciling Item [Line Items]
Total Assets:	290,247	347,750
Operating Segments | Fuel Station Services
Segment Reporting, Asset Reconciling Item [Line Items]
Total Assets:	131,838	119,669
Operating Segments | Corporate
Segment Reporting, Asset Reconciling Item [Line Items]
Total Assets:	$ 29,401	$ 82,204

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Variable Interest Entities - Narrative (Details) - variable_interest_entity	Sep. 30, 2023	Sep. 14, 2023	May 30, 2023	May 29, 2023	Dec. 31, 2022
Variable Interest Entity [Line Items]
Number of variable interest entities	7
Number of variable interest entities consolidated	2			2	4
Paragon
Variable Interest Entity [Line Items]
Percentage of ownership	50.00%		50.00%
Paragon | Emerald And Sapphire
Variable Interest Entity [Line Items]
Percentage of ownership transferred			50.00%
OPAL L2G
Variable Interest Entity [Line Items]
Percentage of ownership		50.00%
SJI LRNG
Variable Interest Entity [Line Items]
Percentage of ownership		50.00%

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Variable Interest Entities - Schedule of Variable Interest Entities on Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 15,000			$ 40,394
Accounts receivable, net	31,000			31,083
Restricted cash - current	1,232			32,402
Environmental credits held for sale	4,339			1,674
Prepaid expenses and other current assets	5,013			7,625
Total current assets	105,785			211,983
Property, plant and equipment, net	303,690			297,323
Restricted cash, non-current	5,356			4,425
Total assets	690,455			644,856
Current liabilities:
Accrued capital expenses	7,355			11,922
Accrued expenses	13,779			9,573
Sunoma Loan- current portion	1,739			380
Total current liabilities	56,930			152,905
Sunoma loan, net of debt issuance costs	20,402			21,712
Total liabilities	253,578			267,037
Equity
Stockholders' equity	(852,944)			(800,601)
Non-redeemable non-controlling interests	884			26,445
Total Stockholders' deficit	(852,060)	$ (760,602)	$ (791,386)	(774,156)	$ (1,039,269)	$ 17,652	$ 6,698	$ 1,202
Total liabilities, Redeemable preferred non-controlling interests, Redeemable non-controlling interests and Stockholders' deficit	690,455			644,856
Related Party
Current liabilities:
Accounts payable	1,365			1,346
Nonrelated Party
Current assets:
Accounts receivable, net				31,083
Current liabilities:
Accounts payable	11,309			22,679
Non-redeemable non-controlling interests
Equity
Total Stockholders' deficit	884	$ 903	$ 27,969	26,445	$ 26,674	$ 17,638	$ 6,684	$ 1,188
Primary Beneficiary
Current assets:
Cash and cash equivalents	1,302			12,506
Accounts receivable, net	79			966
Restricted cash - current	1,232			6,971
Environmental credits held for sale	29			0
Prepaid expenses and other current assets	193			415
Total current assets	2,835			20,858
Property, plant and equipment, net	26,684			73,140
Restricted cash, non-current	2,843			2,923
Total assets	32,362			96,921
Current liabilities:
Accrued capital expenses	0			7,821
Accrued expenses	602			646
Sunoma Loan- current portion	1,739			380
Total current liabilities	3,979			14,176
Sunoma loan, net of debt issuance costs	20,402			21,712
Total liabilities	24,381			35,888
Equity
Stockholders' equity	7,097			34,588
Non-redeemable non-controlling interests	884			26,445
Total Stockholders' deficit	7,981			61,033
Total liabilities, Redeemable preferred non-controlling interests, Redeemable non-controlling interests and Stockholders' deficit	32,362			96,921
Primary Beneficiary | Related Party
Current liabilities:
Accounts payable	1,035			433
Primary Beneficiary | Nonrelated Party
Current liabilities:
Accounts payable	$ 603			$ 4,896

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Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Deficit - Narrative (Details) $ / shares in Units, $ in Thousands					1 Months Ended	3 Months Ended			9 Months Ended		12 Months Ended	14 Months Ended
	Jan. 23, 2023 USD ($) shares	Jul. 21, 2022 $ / shares shares	Jul. 20, 2022 shares	Nov. 29, 2021 project shares	Mar. 31, 2023 USD ($) $ / shares shares	Sep. 30, 2023 USD ($) $ / shares shares	Mar. 31, 2023 USD ($) $ / shares shares	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) dividend_payment $ / shares shares	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($) shares	Sep. 30, 2023 USD ($) $ / shares shares
Preferred Units [Line Items]
Stock issued (in shares)											1,000,000
Fair value of shares acquired | $							$ 11,614
Conversion of stock (in shares)				300,000	49,633
Loss on warrant exchange | $					$ 338	$ 0		$ 0	$ 338	$ 0
Number of noncontrolling interests in renewable natural gas project subsidiaries | project				4
Stock subscribed (in shares)				1,000,000
Amount sold | $											$ 100,000
Preferred stock dividend rate									8.00%
Preferred stock, number of dividend payments to elect to issue additional Preferred Units | dividend_payment									8
Preferred stock dividend rate, event of default									12.00%
Preferred stock dividend rate, event of default, increase for each event									2.00%
Preferred stock dividend rate, event of default, maximum after increases									20.00%
Preferred stock liquidation preference (in dollars per share) | $ / shares						$ 100			$ 100			$ 100
Preferred stock redemption price (in dollars per share) | $ / shares						100			$ 100			100
Preferred stock redemption period after which redeemable									4 years
Preferred stock redemption period after fourth anniversary									30 days
Preferred stock dividend rate if failed to redeem									12.00%
Preferred stock dividend rate, increase to after one year if failed to redeem									14.00%
Preferred stock dividend rate, quarterly increase after one year if failed to redeem									2.00%
Preferred stock dividend rate if failed to redeem, maximum									20.00%
Preferred stock conversion price (in dollars per share) | $ / shares						100			$ 100			100
Preferred stock conversion, first year discount									20.00%
Preferred stock conversion, second year discount									25.00%
Preferred stock conversion, thereafter discount									30.00%
Preferred stock conversion, VWAP period									20 days
Redemption price (in dollars per share) | $ / shares						$ 8.03			$ 8.03			$ 8.03
Meteora | Forward Purchase Agreement
Preferred Units [Line Items]
Contingent consideration, price (in dollars per share) | $ / shares		$ 10.02			$ 10.02		$ 10.02
Fair value of shares acquired | $	$ 11,614								$ 11,614
Offset to derivative liabilities | $						$ 4,777			$ 4,777			$ 4,777
Class A common stock
Preferred Units [Line Items]
Common stock, shares issued (in shares)						29,332,333			29,332,333		29,477,766	29,332,333
Common stock, shares outstanding (in shares)						29,332,333			29,332,333		29,477,766	29,332,333
Common stock, par value (in dollars per share) | $ / shares						$ 0.0001			$ 0.0001			$ 0.0001
Class D common stock
Preferred Units [Line Items]
Common stock, shares issued (in shares)						144,399,037			144,399,037		144,399,037	144,399,037
Common stock, shares outstanding (in shares)						144,399,037			144,399,037		144,399,037	144,399,037
Common stock, par value (in dollars per share) | $ / shares						$ 0.0001			$ 0.0001			$ 0.0001
Class D common stock | Opal Fuels
Preferred Units [Line Items]
Stock issued (in shares)		144,399,037
Class B common stock
Preferred Units [Line Items]
Common stock, shares issued (in shares)						0			0		0	0
Common stock, shares outstanding (in shares)						0			0		0	0
Common stock, par value (in dollars per share) | $ / shares						$ 0.0001			$ 0.0001			$ 0.0001
Class C common stock
Preferred Units [Line Items]
Common stock, shares issued (in shares)						0			0		0	0
Common stock, shares outstanding (in shares)						0			0		0	0
Common stock, par value (in dollars per share) | $ / shares						$ 0.0001			$ 0.0001			$ 0.0001
ArcLight Class A Common STock | Meteora | Forward Purchase Agreement
Preferred Units [Line Items]
Stock issued (in shares)	1,635,783		2,000,000				1,635,783
Class B Ordinary Share | Opal Fuels
Preferred Units [Line Items]
Stock issued (in shares)		144,399,037
Redeemable non-controlling interests
Preferred Units [Line Items]
Change in redemption value of Redeemable non-controlling interests | $						$ 90,834	$ 7,720	$ 1,160,723				$ 1,158,937

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Redeemable non-controlling interests, Redeemable preferred non-controlling interests and Stockholders' Deficit - Changes in Redeemable Preferred Units (Details) - USD ($) $ in Thousands	3 Months Ended					9 Months Ended
	Jun. 30, 2023	Mar. 31, 2023	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2023
Redeemable Preferred non-controlling interests
Increase (Decrease) In Temporary Equity, Amount [Roll Forward]
Beginning balance	$ 140,905	$ 138,142	$ 132,645	$ 55,927	$ 30,210	$ 138,142
Series A units issued by OPAL Fuels						0
Paid-in-kind dividends attributable to OPAL Fuels						1,352
Paid-in kind dividends attributable to Class A common stockholders						7,042
Repayment of paid-in-kind preferred dividends	2,849	2,763	2,658	1,718	717	(16,536)
Ending balance	$ 143,754	$ 140,905	$ 135,303	$ 132,645	$ 55,927	$ 130,000
Series A-1 preferred units
Increase (Decrease) In Temporary Equity, Units [Roll Forward]
Beginning balance (in shares)		300,000				300,000
Ending balance (in shares)						300,000
Increase (Decrease) In Temporary Equity, Amount [Roll Forward]
Beginning balance		$ 32,736				$ 32,736
Paid-in-kind dividends attributable to OPAL Fuels						320
Paid-in kind dividends attributable to Class A common stockholders						1,666
Repayment of paid-in-kind preferred dividends						(4,722)
Ending balance						$ 30,000
Series A preferred units
Increase (Decrease) In Temporary Equity, Units [Roll Forward]
Beginning balance (in shares)		1,000,000				1,000,000
Ending balance (in shares)						1,000,000
Increase (Decrease) In Temporary Equity, Amount [Roll Forward]
Beginning balance		$ 105,406				$ 105,406
Paid-in-kind dividends attributable to OPAL Fuels						1,032
Paid-in kind dividends attributable to Class A common stockholders						5,376
Repayment of paid-in-kind preferred dividends						(11,814)
Ending balance						$ 100,000

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Stock-based compensation - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands			9 Months Ended	12 Months Ended
	Mar. 31, 2023	Jul. 21, 2022	Sep. 30, 2023	Dec. 31, 2022
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock issued (in shares)				1,000,000
Options granted (in shares)	196,961		196,961
Fair value (in dollars per share)	$ 5.26		$ 5.26	$ 0
Closing share price (in dollars per share)	6.97
Exercise price (in dollars per share)	$ 6.97
Fair value	$ 6,955
Stock-based compensation expense related to unvested awards yet to be recognized			$ 7,705
Unrecognized stock-based compensation expense, weighted average period (in years)			2 years 3 months 18 days
Restricted Stock Units (RSUs)
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Awards granted (in shares)	888,831		1,038,347
Restricted Stock Units (RSUs) | Director
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Awards granted (in shares)	135,583
Performance Shares
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Awards granted (in shares)	274,617		274,617
Share-Based Payment Arrangement, Option
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Expiration term (in years)	10 years
Annual risk free interest rate	4.04%
Volatility	65.00%
2022 Omnibus Equity Incentive Plan ("2022 Plan")
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock issued (in shares)		19,811,726

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Stock-based compensation - Summary of Equity Awards (Details) - USD ($) $ / shares in Units, $ in Thousands		9 Months Ended
	Mar. 31, 2023	Sep. 30, 2023
Number of Units outstanding
Number of Units outstanding, beginning balance (in shares)		0
Granted (in shares)	196,961	196,961
Number of Units outstanding, ending balance (in shares)		196,961
Weighted Average Grant Date Fair Value
Number of Units outstanding, Weighted Average Grant Date Fair Value, beginning balance (in dollars per share)		$ 0
Granted (in dollars per share)		5.26
Number of Units outstanding, Weighted Average Grant Date Fair Value, ending balance (in dollars per share)	$ 5.26	$ 5.26
Aggregate Fair Value, Stock Options		$ 1,036
Total unvested awards outstanding (in shares)		1,874,626
Total unvested awards outstanding, Weighted Average Grant Date Fair Value (in dollars per share)		$ 6.87
Total unvested awards outstanding, Aggregate Fair Value		$ 12,873
Restricted Stock Units (RSUs)
Number of Units outstanding
Number of Units outstanding, beginning balance (in shares)		422,349
Granted (in shares)	888,831	1,038,347
Vested in August 2023 (in shares)		(2,135)
Shares withheld for settlement of taxes (in shares)		(1,046)
Forfeitures (in shares)		(50,378)
Number of Units outstanding, ending balance (in shares)		1,407,137
Weighted Average Grant Date Fair Value
Number of Units outstanding, Weighted Average Grant Date Fair Value, beginning balance (in dollars per share)		$ 7.94
Granted, Weighted Average Grant Date Fair Value (in dollars per share)		6.98
Vested in August 2023, Weighted Average Grant Date Fair Value (in dollars per share)		6.97
Forfeitures Weighted Average Grant Date Fair Value (in dollars per share)		7.49
Number of Units outstanding, Weighted Average Grant Date Fair Value, ending balance (in dollars per share)		$ 7.31
Aggregate Fair Value		$ 10,284
Performance Stock Units
Number of Units outstanding
Number of Units outstanding, beginning balance (in shares)		0
Granted (in shares)	274,617	274,617
Vested in August 2023 (in shares)		(83)
Shares withheld for settlement of taxes (in shares)		(31)
Forfeitures (in shares)		(3,975)
Number of Units outstanding, ending balance (in shares)		270,528
Weighted Average Grant Date Fair Value
Granted, Weighted Average Grant Date Fair Value (in dollars per share)		$ 6.97
Forfeitures Weighted Average Grant Date Fair Value (in dollars per share)		6.97
Number of Units outstanding, Weighted Average Grant Date Fair Value, ending balance (in dollars per share)		$ 6.97
Aggregate Fair Value		$ 1,553

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Stock-based compensation - Stock-based Compensation Expense (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Share-Based Payment Arrangement [Abstract]
Stock-based compensation expense	$ 1,899	$ 160	$ 4,747	$ 320

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Net (Loss) Income Per Share - Narrative (Details) - shares	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Mar. 31, 2023	Sep. 30, 2023
Treasury Stock, Common
Class of Warrant or Right [Line Items]
Antidilutive shares (in shares)	1,635,783		1,635,783
Class A common stock
Class of Warrant or Right [Line Items]
Forfeited shares (in shares)		197,258
Class B common stock
Class of Warrant or Right [Line Items]
Antidilutive shares (in shares)			144,399,037
Earnout Target
Class of Warrant or Right [Line Items]
Antidilutive shares (in shares)	763,908		763,908
Sponsor Earnout Awards
Class of Warrant or Right [Line Items]
Antidilutive shares (in shares)			763,908
OPAL Earnout Awards
Class of Warrant or Right [Line Items]
Antidilutive shares (in shares)			10,000,000

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Net (Loss) Income Per Share - Schedule of Basic and Diluted Net Loss Per Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Earnings Per Share [Abstract]
Net (loss) income attributable to Class A common stockholders	$ (400)	$ (1,125)	$ 15,945	$ (1,125)
Weighted average number of shares of Class A common stock - basic (in shares)	26,978,969	25,671,390	27,110,953	25,671,390
Dilutive effect of stock options, restricted stock units, performance units, Convertible note payable, earnout shares, Redeemable preferred non-controlling interests, Redeemable non-controlling interests (in shares)	0		572,902
Weighted average number of shares of Class A common stock - diluted (in shares)	26,978,969	25,823,772	27,683,855	25,823,772
Net loss per share of Class A common stock
Basic (in dollars per share)	$ (0.01)	$ (0.04)	$ 0.59	$ (0.04)
Diluted (in dollars per share)	$ (0.01)	$ (0.06)	$ 0.58	$ (0.06)

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Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Provision for income taxes	$ 0	$ 0	$ 0	$ 0
Effective tax rate	0.00%		0.00%

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Commitments and Contingencies (Details) $ in Thousands	1 Months Ended	9 Months Ended
	Jul. 31, 2015	Sep. 30, 2023 USD ($) standby_letters_of_credit contract	May 30, 2023 USD ($)	Dec. 31, 2022 USD ($) standby_letters_of_credit
Line of Credit Facility [Line Items]
Number of standby letters of credit held | standby_letters_of_credit		5		9
CEI | MD Digester, LLC
Line of Credit Facility [Line Items]
Estimated loss from claim		$ 14,000
Paragon
Line of Credit Facility [Line Items]
Maximum equity commitment letter			$ 2,100
Compressed Natural Gas (CNG)
Line of Credit Facility [Line Items]
Number of purchase option contracts to provide CNG | contract		2
Compressed Natural Gas (CNG) | Minimum
Line of Credit Facility [Line Items]
Term of purchase option contract (in years)		7 years
Compressed Natural Gas (CNG) | Maximum
Line of Credit Facility [Line Items]
Term of purchase option contract (in years)		10 years
Fuel
Line of Credit Facility [Line Items]
Term of purchase option contract (in years)	10 years
Standby Letters of Credit
Line of Credit Facility [Line Items]
Letters of credit outstanding balance		$ 10,498		$ 2,292
Draws on standby letters of credit		$ 0

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Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions	Oct. 20, 2023	Oct. 19, 2023	Sep. 30, 2023	Dec. 31, 2022
Restricted Stock Units (RSUs)
Subsequent Event [Line Items]
Shares outstanding (in shares)			1,407,137	422,349
Subsequent Event | Facility | WGL | RNG Fuel
Subsequent Event [Line Items]
Purchase price	$ 25
Subsequent Event | Class A common stock
Subsequent Event [Line Items]
Option to purchase shares (in shares)		5,545
Exercise price (in dollars per share)		$ 6.97
Subsequent Event | Restricted Stock Units (RSUs)
Subsequent Event [Line Items]
Shares outstanding (in shares)		33,328