Clean Energy Fuels 10Q 2023 Q2 Quarterly report

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended June 30, 2023

☐ 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: 001-33480

CLEAN ENERGY FUELS CORP.

(Exact name of registrant as specified in its charter)

Delaware	33-0968580
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

4675 MacArthur Court, Suite 800, Newport Beach, CA 92660

(Address of principal executive offices, including zip code)

(949) 437-1000

(Registrant’s telephone number, including area code)

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

Title of each class

Trading Symbol(s)

Name of each exchange on which registered

Common stock, $0.0001 par value per share

CLNE

The Nasdaq Stock Market LLC

(Nasdaq Global Select Market)

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 definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.


Large accelerated filer ☒	Accelerated filer ☐

Non-accelerated filer ☐	Smaller reporting company ☐

	Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

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

As of August 2, 2023, there were 222,966,819 shares of the registrant’s common stock, par value $0.0001 per share, issued and outstanding.

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

INDEX

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PART I.—FINANCIAL INFORMATION	3
Item 1.—Financial Statements (Unaudited)	3
Item 2.—Management’s Discussion and Analysis of Financial Condition and Results of Operations	30
Item 3.—Quantitative and Qualitative Disclosures about Market Risk	42
Item 4.—Controls and Procedures	43

PART II.—OTHER INFORMATION	44
Item 1.—Legal Proceedings	44
Item 1A.—Risk Factors	44
Item 2.—Unregistered Sales of Equity Securities and Use of Proceeds	58
Item 3.—Defaults Upon Senior Securities	58
Item 4.—Mine Safety Disclosures	58
Item 5.—Other Information	58
Item 6.—Exhibits	58

Unless the context indicates otherwise, all references to “Clean Energy,” the “Company,” “we,” “us,” or “our” in this report refer to Clean Energy Fuels Corp. together with its consolidated subsidiaries.

This report contains forward-looking statements. See the cautionary note regarding these statements in Part I, Item 2.-Management’s Discussion and Analysis of Financial Condition and Results of Operations of this report.

We own registered or unregistered trademark rights to Clean Energy™. Although we do not use the “®” or “™” symbol in each instance in which one of our trademarks appears in this report, this should not be construed as any indication that we will not assert our rights thereto to the fullest extent under applicable law. Any other service marks, trademarks and trade names appearing in this report are the property of their respective owners.

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PART I.—FINANCIAL INFORMATION

Item 1.—Financial Statements (Unaudited)

Clean Energy Fuels Corp. and Subsidiaries

Condensed Consolidated Balance Sheets

(In thousands, except share and per share data; Unaudited)


	December 31,		June 30,
	2022		2023
Assets
Current assets:
Cash, cash equivalents and current portion of restricted cash	$	125,950	$	55,162
Short-term investments		139,569		138,569
Accounts receivable, net of allowance of $1,375 and $1,501 as of December 31, 2022 and June 30, 2023, respectively		91,430		74,746
Other receivables		17,026		27,088
Inventory		37,144		38,517
Prepaid expenses and other current assets		60,601		58,279
Total current assets		471,720		392,361
Operating lease right-of-use assets		52,586		63,093
Land, property and equipment, net		264,068		292,463
Notes receivable and other long-term assets, net		30,467		31,004
Investments in other entities		193,273		196,770
Goodwill		64,328		64,328
Intangible assets, net		5,915		6,365
Total assets	$	1,082,357	$	1,046,384
Liabilities and Stockholders' Equity
Current liabilities:
Current portion of debt	$	93	$	38
Current portion of finance lease obligations		948		961
Current portion of operating lease obligations		4,206		5,075
Accounts payable		44,435		37,943
Accrued liabilities		90,079		76,609
Deferred revenue		5,970		4,920
Derivative liabilities, related party		2,415		2,779
Total current liabilities		148,146		128,325
Long-term portion of debt		145,471		144,837
Long-term portion of finance lease obligations		2,134		2,024
Long-term portion of operating lease obligations		48,911		59,393
Long-term portion of derivative liabilities, related party		1,430		—
Other long-term liabilities		8,794		8,908
Total liabilities		354,886		343,487
Commitments and contingencies (Note 17)
Stockholders’ equity:
Preferred stock, $0.0001 par value. 1,000,000 shares authorized; no shares issued and outstanding		—		—
Common stock, $0.0001 par value. 454,000,000 shares authorized; 222,437,429 shares and 222,910,057 shares issued and outstanding as of December 31, 2022 and June 30, 2023, respectively		22		22
Additional paid-in capital		1,553,668		1,582,009
Accumulated deficit		(829,975)		(884,973)
Accumulated other comprehensive loss		(3,722)		(1,319)
Total Clean Energy Fuels Corp. stockholders’ equity		719,993		695,739
Noncontrolling interest in subsidiary		7,478		7,158
Total stockholders’ equity		727,471		702,897
Total liabilities and stockholders’ equity	$	1,082,357	$	1,046,384

See accompanying notes to condensed consolidated financial statements.

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Clean Energy Fuels Corp. and Subsidiaries

Condensed Consolidated Statements of Operations

(In thousands, except share and per share data; Unaudited)


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2023		2022		2023
Revenue:
Product revenue	$	85,853	$	75,629	$	158,360	$	195,356
Service revenue		11,371		14,919		22,361		27,375
Total revenue		97,224		90,548		180,721		222,731
Operating expenses:
Cost of sales (exclusive of depreciation and amortization shown separately below):
Product cost of sales		65,933		55,570		123,548		175,228
Service cost of sales		6,127		8,592		12,749		16,202
Selling, general and administrative		26,481		28,548		54,408		58,197
Depreciation and amortization		10,556		10,893		21,946		21,571
Total operating expenses		109,097		103,603		212,651		271,198
Operating loss		(11,873)		(13,055)		(31,930)		(48,467)
Interest expense		(732)		(4,365)		(3,809)		(8,719)
Interest income		490		2,766		754		5,483
Other income, net		14		28		34		71
Loss from equity method investments		(1,193)		(1,915)		(2,870)		(3,805)
Loss before income taxes		(13,294)		(16,541)		(37,821)		(55,437)
Income tax (expense) benefit		(68)		55		(117)		119
Net loss		(13,362)		(16,486)		(37,938)		(55,318)
Loss attributable to noncontrolling interest		127		185		512		320
Net loss attributable to Clean Energy Fuels Corp.	$	(13,235)	$	(16,301)	$	(37,426)	$	(54,998)
Net loss attributable to Clean Energy Fuels Corp. per share:
Basic and diluted	$	(0.06)	$	(0.07)	$	(0.17)	$	(0.25)
Weighted-average common shares outstanding:
Basic and diluted		222,433,900		222,908,402		222,496,426		222,813,286

See accompanying notes to condensed consolidated financial statements.

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Clean Energy Fuels Corp. and Subsidiaries

Condensed Consolidated Statements of Comprehensive Loss

(In thousands; Unaudited)


	Clean Energy Fuels Corp.				Noncontrolling Interest				Total
	Three Months Ended				Three Months Ended				Three Months Ended
	June 30,				June 30,				June 30,
	2022		2023		2022		2023		2022		2023
Net loss	$	(13,235)	$	(16,301)	$	(127)	$	(185)	$	(13,362)	$	(16,486)
Other comprehensive income (loss), net of tax:
Foreign currency translation adjustments, net of $0 tax in 2022 and 2023		(1,297)		585		—		—		(1,297)		585
Unrealized gain (loss) on available-for-sale securities, net of $0 tax in 2022 and 2023		(119)		1,113		—		—		(119)		1,113
Total other comprehensive income (loss)		(1,416)		1,698		—		—		(1,416)		1,698
Comprehensive loss	$	(14,651)	$	(14,603)	$	(127)	$	(185)	$	(14,778)	$	(14,788)


	Clean Energy Fuels Corp.				Noncontrolling Interest				Total
	Six Months Ended				Six Months Ended				Six Months Ended
	June 30,				June 30,				June 30,
	2022		2023		2022		2023		2022		2023
Net loss	$	(37,426)	$	(54,998)	$	(512)	$	(320)	$	(37,938)	$	(55,318)
Other comprehensive income (loss), net of tax:
Foreign currency translation adjustments, net of $0 tax in 2022 and 2023		(1,025)		1,046		—		—		(1,025)		1,046
Unrealized gain (loss) on available-for-sale securities, net of $0 tax in 2022 and 2023		(142)		1,357		—		—		(142)		1,357
Total other comprehensive income (loss)		(1,167)		2,403		—		—		(1,167)		2,403
Comprehensive loss	$	(38,593)	$	(52,595)	$	(512)	$	(320)	$	(39,105)	$	(52,915)

See accompanying notes to condensed consolidated financial statements.

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Clean Energy Fuels Corp. and Subsidiaries

Condensed Consolidated Statements of Stockholders’ Equity

(In thousands, except share data; Unaudited)


								Accumulated
				Additional				Other		Noncontrolling		Total
	Common Stock			Paid-In		Accumulated		Comprehensive		Interest in		Stockholders’
	Shares	Amount		Capital		Deficit		Loss		Subsidiary		Equity
Balance, December 31, 2021	222,684,923	$	22	$	1,519,918	$	(771,242)	$	(1,622)	$	8,335	$	755,411
Issuance of common stock	585,775		—		273		—		—		—		273
Repurchase of common stock	(511,010)				(3,001)		—		—		—		(3,001)
Stock-based compensation	—		—		8,253		—		—		—		8,253
Stock-based sales incentive charges	—		—		1,721		—		—		—		1,721
Net loss	—		—		—		(24,191)		—		(385)		(24,576)
Other comprehensive income	—		—		—		—		249		—		249
Balance, March 31, 2022	222,759,688		22		1,527,164		(795,433)		(1,373)		7,950		738,330
Issuance of common stock	96,728		—		300		—		—		—		300
Repurchase of common stock	(679,244)		—		(3,121)		—		—		—		(3,121)
Stock-based compensation	—		—		6,468		—		—		—		6,468
Stock-based sales incentive charges	—		—		2,307		—		—		—		2,307
Net loss	—		—		—		(13,235)		—		(127)		(13,362)
Other comprehensive loss	—		—		—		—		(1,416)		—		(1,416)
Balance, June 30, 2022	222,177,172	$	22	$	1,533,118	$	(808,668)	$	(2,789)	$	7,823	$	729,506


								Accumulated
				Additional				Other		Noncontrolling		Total
	Common Stock			Paid-In		Accumulated		Comprehensive		Interest in		Stockholders’
	Shares	Amount		Capital		Deficit		Loss		Subsidiary		Equity
Balance, December 31, 2022	222,437,429	$	22	$	1,553,668	$	(829,975)	$	(3,722)	$	7,478	$	727,471
Issuance of common stock	470,351		—		332		—		—		—		332
Shares withheld related to net share settlement	—		—		(175)		—		—		—		(175)
Stock-based compensation	—		—		6,096		—		—		—		6,096
Stock-based sales incentive charges	—		—		8,172		—		—		—		8,172
Net loss	—		—		—		(38,697)		—		(135)		(38,832)
Other comprehensive income	—		—		—		—		705		—		705
Balance, March 31, 2023	222,907,780		22		1,568,093		(868,672)		(3,017)		7,343		703,769
Issuance of common stock	2,277		—		3		—		—		—		3
Stock-based compensation	—		—		6,093		—		—		—		6,093
Stock-based sales incentive charges	—		—		7,820		—		—		—		7,820
Net loss	—		—		—		(16,301)		—		(185)		(16,486)
Other comprehensive income	—		—		—		—		1,698		—		1,698
Balance, June 30, 2023	222,910,057	$	22	$	1,582,009	$	(884,973)	$	(1,319)	$	7,158	$	702,897

See accompanying notes to condensed consolidated financial statements.

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Clean Energy Fuels Corp. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(In thousands; Unaudited)


		Six Months Ended June 30,
	2022		2023
Cash flows from operating activities:
Net loss	$	(37,938)	$	(55,318)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depreciation and amortization		21,946		21,571
Provision for credit losses and inventory		1,006		1,006
Stock-based compensation expense		14,721		12,189
Stock-based sales incentive charges		8,533		27,652
Change in fair value of derivative instruments		2,114		(1,068)
Amortization of discount and debt issuance cost		(306)		(2,190)
Gain on disposal of property and equipment		(66)		(101)
Loss on extinguishment of debt		2,268		—
Asset impairments and other charges		—		482
Loss from equity method investments		2,870		3,805
Non-cash lease expense		1,687		2,919
Deferred income taxes		62		(165)
Changes in operating assets and liabilities:
Accounts and other receivables		19,024		16,518
Inventory		(4,487)		(3,489)
Prepaid expenses and other assets		(2,002)		(6,956)
Operating lease liabilities		(1,747)		(2,075)
Accounts payable		6,912		(6,351)
Deferred revenue		(1,034)		(1,050)
Accrued liabilities and other		(1,325)		(14,341)
Net cash provided by (used in) operating activities		32,238		(6,962)
Cash flows from investing activities:
Purchases of short-term investments		(194,353)		(186,273)
Maturities and sales of short-term investments		194,250		190,500
Purchases of and deposits on property and equipment		(17,447)		(42,754)
Grant proceeds for capital projects		—		1,947
Disbursements for loans receivable		(516)		(2,340)
Proceeds from paydowns, maturities, and sales of loans receivables		218		1,612
Cash received from sale of certain assets of subsidiary, net		3,885		—
Investments in other entities		(51,600)		(5,500)
Payment and deposits on equipment and manure rights for RNG production projects		(4,915)		(15,080)
Proceeds received for joint development and construction of station projects		—		1,172
Advance to DR JV		—		(5,500)
Proceeds from disposal of property and equipment		80		198
Net cash (used in) investing activities		(70,398)		(62,018)
Cash flows from financing activities:
Issuance of common stock		573		335
Repurchase of common stock		(6,122)		—
Payments of tax withholdings on net settlement of equity awards		—		(175)
Fees paid for lender and debt issuance costs		(50)		(1,440)
Proceeds for Adopt-a-Port program		890		150
Repayment of proceeds for Adopt-a-Port program		(525)		(705)
Proceeds from debt instruments		14,000		255
Repayments of debt instruments and finance lease obligations		(17,315)		(612)
Payments of debt extinguishment costs		(2,186)		—
Net cash (used in) financing activities		(10,735)		(2,192)
Effect of exchange rates on cash, cash equivalents and restricted cash		(66)		384
Net (decrease) in cash, cash equivalents and restricted cash		(48,961)		(70,788)
Cash, cash equivalents and restricted cash, beginning of period		106,456		125,950
Cash, cash equivalents and restricted cash, end of period	$	57,495	$	55,162
Supplemental disclosure of cash flow information:
Income taxes paid	$	50	$	57
Interest paid, net of $0 and $581 capitalized, respectively	$	923	$	8,279

See accompanying notes to condensed consolidated financial statements.

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Clean Energy Fuels Corp. and Subsidiaries

Notes to Condensed Consolidated Financial Statements

(Unaudited)

Note 1—General

Nature of Business

Clean Energy Fuels Corp., together with its majority and wholly owned subsidiaries (hereinafter collectively referred to as the “Company,” unless the context or the use of the term indicates or requires otherwise) is engaged in the business of selling renewable and conventional natural gas as alternative fuels for vehicle fleets and related fueling solutions to its customers, primarily in the United States and Canada. The Company’s principal business is supplying renewable natural gas (“RNG”) and conventional natural gas, in the form of compressed natural gas (“CNG”) and liquefied natural gas (“LNG”), for medium and heavy-duty vehicles and providing operation and maintenance (“O&M”) services to public and private vehicle fleet customer stations. The Company is also focused on developing, owning, and operating dairy and other livestock waste RNG projects and supplying RNG (currently procured solely from third party sources and will be supplemented by internally produced RNG when the Company’s RNG projects come online) to its customers in the heavy and medium-duty commercial transportation sector.

As a comprehensive clean energy solution provider, the Company also designs and builds, as well as operates and maintains, public and private vehicle fueling stations in the United States and Canada; sells and services compressors and other equipment used in RNG production and at fueling stations; transports and sells RNG and conventional natural gas, in the form of CNG and LNG, via “virtual” natural gas pipelines and interconnects; sells U.S. federal, state and local government credits it generates by selling RNG in the form of CNG and LNG as a vehicle fuel, including Renewable Identification Numbers (“RIN Credits” or “RINs”) under the federal Renewable Fuel Standard Phase 2 and credits under the California and the Oregon Low Carbon Fuel Standards (collectively, “LCFS Credits”); and obtains federal, state and local tax credits, grants and incentives.

Basis of Presentation

The accompanying interim unaudited condensed consolidated financial statements include the accounts of the Company and its subsidiaries, and, in the opinion of management, reflect all adjustments, which include only normal recurring adjustments, necessary to state fairly the Company’s consolidated financial position as of June 30, 2023, results of operations, comprehensive loss, and stockholders’ equity for the three and six months ended June 30, 2022 and 2023, and cash flows for the six months ended June 30, 2022 and 2023. All intercompany accounts and transactions have been eliminated in consolidation. The results of operations for the three and six months ended June 30, 2022 and 2023 are not necessarily indicative of the results to be expected for the year ending December 31, 2023 or for any other interim period or any future year.

Certain information and disclosures normally included in the notes to consolidated financial statements have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”), but the resultant disclosures contained herein are in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) as they apply to interim reporting. The accompanying condensed consolidated financial statements should be read in conjunction with the consolidated financial statements as of and for the year ended December 31, 2022 that are included in the Company’s Annual Report on Form 10-K filed with the SEC on February 28, 2023.

Use of Estimates

The preparation of condensed consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the amounts reported in the accompanying condensed consolidated financial statements and these notes. Actual results could differ from those estimates and may result in

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material effects on the Company’s operating results and financial position. Significant estimates made in preparing the accompanying condensed consolidated financial statements include (but are not limited to) those related to revenue recognition, fair value measurements, goodwill and long-lived asset valuations and impairment assessments, income tax valuations, stock-based compensation expense and stock-based sales incentive charges.

Amazon Warrant

The Amazon Warrant (defined in Note 14) is accounted for as an equity instrument and measured in accordance with Accounting Standards Codification (“ASC”) 718, Compensation – Stock Compensation. This instrument is classified in the condensed consolidated statements of operations in accordance with ASC 606, Revenue from Contracts with Customers, which states that for awards granted to a customer that are not in exchange for distinct goods or services, the fair value of the awards earned based on service or performance conditions is recorded as a reduction of the transaction price. To determine the fair value of the Amazon Warrant in accordance with ASC 718, the Company used the Black-Scholes option pricing model, which is based in part on assumptions that require management to use judgment. Based on the fair value of the award, the Company determines the amount of non-cash stock-based sales incentive charges on the customer’s pro-rata achievement of vesting conditions, which is recorded as a reduction of revenue in the condensed consolidated statements of operations. See Note 14 for additional information.

Tourmaline Joint Development

In April 2023, the Company and Tourmaline Oil Corp. (“Tourmaline”) announced a CAD $70 million Joint Development Agreement to build and operate a network of CNG stations along key highway corridors across Western Canada. Under a 50-50 shared investment, the Company and Tourmaline expect to construct and commission up to 20 CNG fueling stations over the next five years, allowing heavy-duty trucks and other commercial transportation fleets that operate in the area to transition to the use of CNG, a lower carbon alternative to gasoline and diesel. Costs associated with station construction and profit and loss arising from station operation are shared 50-50 between the Company and Tourmaline. This arrangement between the Company and Tourmaline to jointly develop, build and operate CNG fueling stations is accounted for in accordance with ASC 808, Collaborative Arrangements, which states that (1) costs incurred and revenue generated from transactions with third parties be separately recorded by each participant in its own financial statements, (2) the participant who is deemed to be the principal for a given transaction under ASC 606, Revenue from Contracts with Customers, will record the transaction on a gross basis in its financial statements, and (3) payments between participants that are within the scope of other authoritative accounting literature on income statement classification shall be accounted for using the relevant provisions of that literature. If the payments are not within the scope of other authoritative accounting literature, then the income statement classification for the payments shall be based on an analogy to authoritative accounting literature or if there is no appropriate analogy, a reasonable, rational, and consistently applied accounting policy election.

The Company determined that it is the principal for the revenue generated from third parties under this collaborative arrangement with Tourmaline in accordance with ASC 606; as such, the associated revenue and cost of sales generated and incurred are recognized on a gross basis in the condensed consolidated statements of operations. Net participation of profit and loss owed to or from Tourmaline is recorded as an increase or decrease to cost of sales, respectively, as the transaction is not deemed to be with a customer within the scope of ASC 606. Capitalized station costs are presented at half of the total development and construction costs in the condensed consolidated balance sheets, corresponding to the Company’s 50% ownership in the shared assets.

Recently Issued Accounting Pronouncements

In March 2023, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2023-01, Leases (Topic 842): Common Control Arrangements. This ASU permits private entities with common control arrangements that may contain or be leases to use any written terms and conditions between the parties, without regard to their legal enforceability, to identify, classify and account for common control leases. In addition, all lessees (public or private), in general, amortize leasehold improvements related to a common control lease over their useful life to the common control group, regardless of the ASC 842 lease term, as long as they continue to control the use of the underlying leased asset. The ASU is effective for fiscal years, including interim periods within those years, beginning after

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December 15, 2023, with early adoption allowed. The Company is currently evaluating the impact of adopting this new ASU and does not expect the adoption to have a material effect on the Company’s condensed consolidated financial statements.

Note 2—Revenue from Contracts with Customers

Revenue Recognition Overview

The Company recognizes revenue when control of the promised goods or services is transferred to its customers, in an amount that reflects the consideration to which it expects to be entitled in exchange for the goods or services. To achieve that core principle, a five-step approach is applied: (1) identify the contract with a customer, (2) identify the performance obligations in the contract, (3) determine the transaction price, (4) allocate the transaction price to the performance obligations in the contract, and (5) recognize revenue allocated to each performance obligation when the Company satisfies the performance obligation. A performance obligation is a promise in a contract to transfer a distinct good or service to the customer, and is the unit of account for revenue recognition.

The Company is generally the principal in its customer contracts because it has control over the goods and services prior to their transfer to the customer, and as such, revenue is recognized on a gross basis. Sales and usage-based taxes are excluded from revenue. Revenue is recognized net of allowances for returns and any taxes collected from customers, which are subsequently remitted to governmental authorities. The table below presents the Company’s revenue disaggregated by revenue source (in thousands):


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2023		2022		2023
Product revenue:
Volume-related
Fuel sales⁽¹⁾	$	67,094	$	53,267	$	125,712	$	160,162
Change in fair value of derivative instruments⁽²⁾		(1,079)		3,600		(2,114)		1,068
RIN Credits		9,795		5,377		17,727		9,880
LCFS Credits		4,085		2,474		7,519		4,772
AFTC ⁽³⁾		(9)		5,059		222		9,555
Total volume-related product revenue		79,886		69,777		149,066		185,437
Station construction sales		5,967		5,852		9,294		9,919
Total product revenue		85,853		75,629		158,360		195,356
Service revenue:
Volume-related, O&M services		11,035		13,913		21,745		25,957
Other services		336		1,006		616		1,418
Total service revenue		11,371		14,919		22,361		27,375
Total revenue	$	97,224	$	90,548	$	180,721	$	222,731

(1)

Includes non-cash stock-based sales incentive contra-revenue charges associated with the Amazon Warrant. For the three and six months ended June 30, 2022, contra-revenue charges recognized in fuel revenue were $4.8 million and $8.5 million, respectively. For the three and six months ended June 30, 2023, contra-revenue charges recognized in fuel revenue were $13.9 Million and $27.7 million, respectively. See Note 14 for more information.

(2)

Represents changes in fair value of derivative instruments related to the Company’s commodity swap and customer fueling contracts associated with the Company’s Zero Now truck financing program. The amounts are classified as revenue because the Company’s commodity swap contracts are used to economically offset the risk associated with the diesel-to-natural gas price spread resulting from customer fueling contracts under the Company’s Zero Now truck financing program. See Note 6 for more information about these derivative instruments.

(3)	Represents the federal alternative fuel excise tax credit (“AFTC”). See Note 19 for more information.

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Remaining Performance Obligations

Remaining performance obligations represent the transaction price of customer orders for which the work has not been performed. As of June 30, 2023, the aggregate amount of the transaction price allocated to remaining performance obligations was $28.5 million, which related to the Company’s station construction sale contracts. The Company expects to recognize revenue on the remaining performance obligations under these contracts over the next 12 to 24 months.

For volume-related revenue, the Company has elected to apply an optional exemption, which waives the requirement to disclose the remaining performance obligation for revenue recognized through the ‘right to invoice’ practical expedient.

Contract Balances

The timing of revenue recognition, billings and cash collections results in billed accounts receivable, unbilled receivables (contract assets), and customer advances and deposits (contract liabilities) in the accompanying condensed consolidated balance sheets.

As of December 31, 2022 and June 30, 2023, the Company’s contract balances were as follows (in thousands):


	December 31,		June 30,
	2022		2023
Accounts receivable, net	$	91,430	$	74,746

Contract assets - current	$	6,063	$	8,724
Contract assets - non-current		2,976		2,699
Contract assets - total	$	9,039	$	11,423

Contract liabilities - current	$	5,477	$	3,329
Contract liabilities - non-current		—		—
Contract liabilities - total	$	5,477	$	3,329

Accounts Receivable, Net

“Accounts receivable, net” in the accompanying condensed consolidated balance sheets includes billed and accrued amounts that are currently due from customers. The amounts due are stated at their net estimated realizable value. The Company maintains an allowance to provide for the estimated amount of receivables that will not be collected. The allowance is based on an assessment of customer creditworthiness, historical payment experience, the age of outstanding receivables, and economic conditions that may affect a customer’s ability to pay.

Contract Assets

Contract assets include unbilled amounts typically resulting from the Company’s station construction sale contracts, when the cost-to-cost method of revenue recognition is utilized and revenue recognized exceeds the amount billed to the customer, and right to payment is not just subject to the passage of time. Amounts may not exceed their net realizable value. Contract assets are classified as current or noncurrent based on the timing of billings. The current portion is included in “Other receivables” and in “Prepaid expenses and other current assets” and the noncurrent portion is included in “Notes receivable and other long-term assets, net” in the accompanying condensed consolidated balance sheets.

Contract Liabilities

Contract liabilities consist of billings in excess of revenue recognized from the Company’s station construction sale contracts and payments received primarily from customers of NG Advantage, LLC (“NG Advantage”) in advance of the satisfaction of performance obligations and are classified as current or noncurrent based on when the related revenue

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is expected to be recognized. The current portion and noncurrent portion of contract liabilities are included in “Deferred revenue” and in “Other long-term liabilities,” respectively, in the accompanying condensed consolidated balance sheets.

Revenue recognized in the six months ended June 30, 2022 relating to the Company’s contract liability balances as of December 31, 2021 was $0.9 million. The decrease in the contract liability balance in the six months ended June 30, 2023 is primarily driven by $3.3 million of revenue recognized relating to the Company’s contract liability balance as of December 31, 2022, partially offset by billings in excess of revenue recognized in the six months ended June 30, 2023.

Note 3— Investments in Other Entities and Noncontrolling Interest in a Subsidiary

TotalEnergies Joint Venture

On March 3, 2021, the Company entered into an agreement (the “TotalEnergies JV Agreement”) with TotalEnergies S.E. (“TotalEnergies”) to create 50/50 joint ventures to develop anaerobic digester gas (“ADG”) RNG production facilities in the United States. Pursuant to the TotalEnergies JV Agreement, each ADG RNG production facility project will be formed as a separate limited liability company (“LLC”) that is owned 50/50 by the Company and TotalEnergies, and contributions to such LLCs count toward the TotalEnergies JV Equity Obligations (as defined below). The TotalEnergies JV Agreement contemplates investing up to $400.0 million of equity in production projects, and TotalEnergies and the Company each committed to initially provide $50.0 million (the “TotalEnergies JV Equity Obligations”). In October 2021, TotalEnergies and the Company executed a LLC agreement (the “DR Development Agreement”) for an ADG RNG production facility project (the “DR JV”). Under the DR Development Agreement, TotalEnergies and the Company have each committed to contribute $7.0 million to the DR JV, and in November 2021, TotalEnergies and the Company each contributed an initial $4.8 million to the DR JV. On June 28, 2023, the DR JV issued a capital call for $11.0 million in additional funding, requiring TotalEnergies and the Company each to contribute $5.5 million. Funds from the capital call will be used to fund required loan reserves and to paydown outstanding liabilities of the DR JV. On June 30, 2023, the Company contributed $5.5 million and advanced $5.5 million to the DR JV. The $5.5 million advance is expected to be refunded to the Company by the DR JV before the end of 2023.

The Company accounts for its interest in the LLC using the equity method of accounting because the Company does not control but has the ability to exercise significant influence over the LLC’s operations. The Company recorded a loss of $0.1 million and $1.0 million from the LLC’s operations in the three months ended June 30, 2022 and 2023, respectively, and a loss of $0.1 million and $1.4 million from the LLC’s operations in the six months ended June 30, 2022 and 2023, respectively. The Company had an investment balance of $4.5 million and $8.6 million as of December 31, 2022 and June 30, 2023, respectively.

bp Joint Venture

On April 13, 2021, the Company entered into an agreement (the “bp JV Agreement”) with bp Products North America, Inc. (“bp”) that created a 50/50 joint venture (the “bpJV”) to develop, own and operate new ADG RNG production facilities in the United States. Pursuant to the bp JV Agreement, bp and the Company committed to provide $50.0 million and $30.0 million, respectively, with bp and the Company each receiving 30.0 million of Class A Units in the bpJV and bp also receiving 20.0 million of Class B Units in the bpJV. bp’s initial $50.0 million contribution was made on April 13, 2021 and consisted of all unpaid principal outstanding under the loan agreement dated December 18, 2020, pursuant to which bp advanced $50.0 million to the Company to fund capital costs and expenses incurred prior to formation of the bpJV, including capital costs and expenses for permitting, engineering, equipment, leases and feed stock rights.

Pursuant to the bp JV Agreement, the Company had the option, exercisable prior to August 31, 2021 (the “bp Option”), to commit an additional $20.0 million to the bpJV upon which bp’s Class B Units would convert into Class A Units. On June 21, 2021, the Company contributed $50.2 million to the bpJV, which consisted of (i) its initial contribution commitment of $30.0 million, (ii) the $20.0 million additional contribution to effect the conversion of bp’s Class B Units into Class A Units pursuant to the Company’s exercise of the bp Option, and (iii) $0.2 million for interest in accordance with the bp JV Agreement to effect the conversion of bp’s Class B Units into Class A Units.

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In December 2021, the bpJV issued a capital call for $143.2 million in additional funding, requiring bp and the Company each to contribute $71.6 million, and, in March 2022, the bpJV issued a second capital call for $76.2 million in additional funding, requiring bp and the Company each to contribute $38.1 million. Pursuant to the bpJV capital calls, the Company contributed $20.0 million, $51.6 million and $38.1 million in December 2021, June 2022 and September 2022, respectively, satisfying in full the Company’s contribution obligations under these capital calls. As of June 30, 2023, bp and the Company each own 50% of the bpJV. 100% of the RNG produced from the projects developed and owned by the bpJV will be available to the Company pursuant to the Company’s marketing agreement with bp.

The Company accounts for its interest in the bpJV using the equity method of accounting because the Company does not control but has the ability to exercise significant influence over the bpJV’s operations. The Company recorded a loss of $0.8 million and $0.2 million from this investment in the three months ended June 30, 2022 and 2023, respectively, and a loss of $2.0 million and $0.6 million from this investment in the six months ended June 30, 2022 and 2023, respectively. The Company had an investment balance in the bpJV of $156.8 million and $156.2 million as of December 31, 2022 and June 30, 2023, respectively.

SAFE&CEC S.r.l.

On November 26, 2017, the Company, through its former subsidiary, IMW Industries Ltd. (formerly known as Clean Energy Compression Corp.) (“CEC”), entered into an investment agreement with Landi Renzo S.p.A. (“LR”), an alternative fuels company based in Italy. Pursuant to the investment agreement, the Company and LR agreed to combine their respective natural gas compressor fueling systems manufacturing subsidiaries, CEC and SAFE S.p.A, into a new company, SAFE&CEC S.r.l. (such combination transaction is referred to as the “CEC Combination”). SAFE&CEC S.r.l. is focused on manufacturing, selling and servicing natural gas fueling compressors and related equipment for the global natural gas fueling market. At the closing of the CEC Combination on December 29, 2017, the Company owned 49% of SAFE&CEC S.r.l., and LR owned 51% of SAFE&CEC S.r.l.

The Company accounts for its interest in SAFE&CEC S.r.l. using the equity method of accounting because the Company does not control but has the ability to exercise significant influence over SAFE&CEC S.r.l.’s operations. The Company recorded a loss of $0.1 million and a gain of $0.2 million in the three months ended June 30, 2022 and 2023, respectively, and a loss of $0.2 million and $0.3 million in the six months ended June 30, 2022 and 2023, respectively. The Company had an investment balance in SAFE&CEC S.r.l. of $21.8 million and $22.2 million as of December 31, 2022 and June 30, 2023, respectively.

NG Advantage

On October 14, 2014, the Company entered into a Common Unit Purchase Agreement (“UPA”) with NG Advantage for a 53.3% controlling interest in NG Advantage. Subsequently, the Company’s controlling interest increased in connection with various equity and financing arrangements with NG Advantage. As of June 30, 2023, the Company’s controlling interest in NG Advantage was 93.3%. NG Advantage is engaged in the business of transporting CNG in high-capacity trailers to industrial and institutional energy users, such as hospitals, food processors, manufacturers and paper mills that do not have direct access to natural gas pipelines.

The Company recorded a loss attributable to the noncontrolling interest in NG Advantage of $0.1 million and $0.2 million in the three months ended June 30, 2022 and 2023, respectively, and a loss attributable to the noncontrolling interest in NG Advantage of $0.5 million and $0.3 million in the six months ended June 30, 2022 and 2023, respectively. The value of the noncontrolling interest was $7.5 million and $7.2 million as of December 31, 2022 and June 30, 2023, respectively.

Investments in Equity Securities

For investments in equity securities of privately held entities without readily determinable fair values, the Company measures such investments at cost, adjusted for impairment, if any, and observable price changes in orderly transactions for the identical or similar investment of the same issuer. As of December 31, 2022 and June 30, 2023, the

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Company had an investment balance recorded at cost of $8.0 million. The Company did not recognize any adjustments to the recorded cost basis in the three and six months ended June 30, 2022 and 2023.

Note 4—Cash, Cash Equivalents and Restricted Cash

Cash, cash equivalents and restricted cash as of December 31, 2022 and June 30, 2023 consisted of the following (in thousands):


	December 31,		June 30,
	2022		2023
Current assets:
Cash and cash equivalents	$	123,950	$	53,150
Restricted cash - standby letter of credit		2,000		2,012
Total cash, cash equivalents and current portion of restricted cash	$	125,950	$	55,162

Total cash, cash equivalents and restricted cash	$	125,950	$	55,162

The Company considers all highly liquid investments with maturities of three months or less on the date of acquisition to be cash equivalents.

The Company places its cash and cash equivalents with high credit quality financial institutions. At times, such balances may be in excess of the Federal Deposit Insurance Corporation (“FDIC”) and Canadian Deposit Insurance Corporation (“CDIC”) limits. Financial instruments that potentially subject the Company to concentrations of credit risk consist principally of cash deposits. The amounts in excess of FDIC and CDIC limits were approximately $124.8 million and $54.0 million as of December 31, 2022 and June 30, 2023, respectively.

The Company classifies restricted cash as short-term and a current asset if the cash is expected to be used in operations within a year or to acquire a current asset. Otherwise, the restricted cash is classified as long-term. The Company deposited $2.0 million, in the form of a certificate of deposit, at PlainsCapital Bank as collateral for the standby letter of credit issued to Chevron Products Company, a division of Chevron U.S.A. Inc., in connection with the Company’s Adopt-A-Port program. The $2.0 million certificate of deposit is classified as short-term restricted cash and a current asset and is included in “Cash, cash equivalents and current portion of restricted cash” in the accompanying condensed consolidated balance sheets as of December 31, 2022 and June 30, 2023.

Note 5—Short-Term Investments

Short-term investments include available-for-sale debt securities, excluded from cash equivalents, that have maturities of one year or less on the date of acquisition and certificates of deposit. Available-for-sale debt securities are carried at fair value, inclusive of unrealized gains and losses. Unrealized gains and losses on available-for-sale debt securities are recognized in other comprehensive income (loss), net of applicable income taxes. Gains or losses on sales of available-for-sale debt securities are recognized on the specific identification basis.

The Company reviews available-for-sale debt securities for declines in fair value below their cost basis each quarter and whenever events or changes in circumstances indicate that the cost basis of an asset may not be recoverable and evaluates the current expected credit loss. This evaluation is based on a number of factors, including historical experience, market data, issuer-specific factors, economic conditions, and any changes to the credit rating of the security. As of June 30, 2023, the Company has not recorded a credit loss related to available-for-sale debt securities and believes the carrying values of its available-for-sale debt securities are properly recorded.

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Short-term investments as of December 31, 2022 consisted of the following (in thousands):


			Gross
	Amortized		Unrealized		Estimated
	Cost		Gain (Loss)		Fair Value
Zero coupon bonds	$	74,524	$	(365)	$	74,159
U.S. government securities		64,861		19		64,880
Certificates of deposit		530		—		530
Total short-term investments	$	139,915	$	(346)	$	139,569

Short-term investments as of June 30, 2023 consisted of the following (in thousands):


			Gross
	Amortized		Unrealized		Estimated
	Cost		Gain (Loss)		Fair Value
U.S. government securities	$	137,999	$	40	$	138,039
Certificates of deposit		530		—		530
Total short-term investments	$	138,529	$	40	$	138,569

Note 6—Derivative Instruments and Hedging Activities

In October 2018, the Company executed two commodity swap contracts with TotalEnergies Gas & Power North America, an affiliate of TotalEnergies and THUSA (as defined in Note 12), for a total of 5.0 million diesel gallons annually from April 1, 2019 to June 30, 2024. These commodity swap contracts are used to manage diesel price fluctuation risks related to the natural gas fuel supply commitments the Company makes in its fueling agreements with fleet operators that participate in the Zero Now truck financing program. These contracts are not designated as accounting hedges and as a result, changes in the fair value of these derivative instruments are recognized in “Product revenue” in the accompanying condensed consolidated statements of operations.

The Company has entered into fueling agreements with fleet operators under the Zero Now truck financing program. Certain of these fueling agreements contain a pricing feature indexed to diesel, which the Company determined to be an embedded derivative and is recorded at fair value at the time of execution, with the changes in fair value of the embedded derivative recognized in “Product revenue” in the accompanying condensed consolidated statements of operations.

Commodity swaps and embedded derivatives as of December 31, 2022 consisted of the following (in thousands):


	Gross Amounts		Gross Amounts		Net Amount
	Recognized		Offset		Presented
Assets:
Fueling agreements:
Prepaid expenses and other current assets	$	1,640	$	—	$	1,640
Notes receivable and other long-term assets, net		5,115		—		5,115
Total derivative assets	$	6,755	$	—	$	6,755
Liabilities:
Commodity swaps:
Current portion of derivative liabilities, related party	$	2,415	$	—	$	2,415
Long-term portion of derivative liabilities, related party		1,430		—		1,430
Total derivative liabilities	$	3,845	$	—	$	3,845

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Commodity swaps and embedded derivatives as of June 30, 2023 consisted of the following (in thousands):


	Gross Amounts		Gross Amounts		Net Amount
	Recognized		Offset		Presented
Assets:
Fueling agreements:
Prepaid expenses and other current assets	$	2,299	$	—	$	2,299
Notes receivable and other long-term assets, net		4,538		—		4,538
Total derivative assets	$	6,837	$	—	$	6,837
Liabilities:
Commodity swaps:
Current portion of derivative liabilities, related party	$	2,779	$	—	$	2,779
Fueling agreements:
Accrued liabilities		80		—		80
Total derivative liabilities	$	2,859	$	—	$	2,859

As of December 31, 2022 and June 30, 2023, the Company had a total volume on open commodity swap contracts of 6.9 million and 4.4 million diesel gallons, respectively, at a weighted-average price of approximately $3.18 per gallon.

The following table reflects the weighted-average price of open commodity swap contracts as of December 31, 2022 and June 30, 2023, by year with associated volumes:


	December 31, 2022			June 30, 2023
	Volumes	Weighted-Average Price per		Volumes	Weighted-Average Price per
Year	(Diesel Gallons)	Diesel Gallon		(Diesel Gallons)	Diesel Gallon
2023	5,000,000	$	3.18	2,500,000	$	3.18
2024	1,875,000	$	3.18	1,875,000	$	3.18

Note 7—Fair Value Measurements

The Company follows the authoritative guidance for fair value measurements with respect to assets and liabilities that are measured at fair value on a recurring basis and non-recurring basis. Under the standard, fair value is defined as the exit price, or the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants, as of the measurement date. The standard also establishes a hierarchy for inputs used in measuring fair value that maximizes the use of observable inputs and minimizes the use of unobservable inputs by requiring that the most observable inputs be used when available. Observable inputs are inputs developed based on market data obtained from sources independent of the Company that market participants would use in valuing the asset or liability. Unobservable inputs are inputs that reflect the Company’s assumptions about the factors market participants would use in valuing the asset or liability developed based upon the best information available in the circumstances. The hierarchy consists of the following three levels: Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities; Level 2 inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, and inputs (other than quoted prices) that are observable for the asset or liability, either directly or indirectly; and Level 3 inputs are unobservable inputs for the asset or liability. Categorization within the valuation hierarchy is based upon the lowest level of input that is significant to the fair value measurement.

Assets and Liabilities Measured at Fair Value on a Recurring Basis

The Company’s U.S. government issued debt securities are classified within Level 1 because they are valued using the most recent quoted prices for identical assets in active markets. Zero coupon bonds and certificate of deposits are classified within Level 2 because they are valued using the most recent quoted prices for identical assets in markets that are not active and quoted prices for similar assets in active markets.

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The Company used the income approach to value its outstanding commodity swap contracts and embedded derivatives in its fueling agreements under the Zero Now truck financing program (see Note 6). Under the income approach, the Company used a discounted cash flow (“DCF”) model in which cash flows anticipated over the term of the contracts are discounted to their present value using an expected discount rate. The discount rate used for cash flows reflects the specific risks in spot and forward rates and credit valuation adjustments. This valuation approach is considered a Level 3 fair value measurement. The significant unobservable inputs used in the fair value measurement of the Company’s derivative instruments are Ultra-Low Sulfur Diesel (“ULSD”) forward prices and differentials from ULSD to Petroleum Administration for Defense District (“PADD”) regions. Significant increases (decreases) in any of those inputs in isolation would result in a significantly lower (higher) fair value measurement. Generally, a change in the ULSD forward prices is accompanied by a directionally opposite but less extreme change in the ULSD-PADD differential.

The Company estimated the fair value of its outstanding commodity swap contracts based on the following inputs as of December 31, 2022 and June 30, 2023:


	December 31, 2022			June 30, 2023
Significant Unobservable Inputs	Input Range	Weighted Average		Input Range	Weighted Average
ULSD Gulf Coast Forward Curve	$2.35 - $2.59	$	2.48	$1.98 - $2.23	$	2.13
Historical Differential to PADD 3 Diesel	$0.88 - $1.62	$	1.13	$0.92 - $1.62	$	1.14
Historical Differential to PADD 5 Diesel	$1.89 - $3.00	$	2.30	$1.89 - $3.02	$	2.36

The Company estimated the fair value of embedded derivatives in its fueling agreements under the Zero Now truck financing program based on the following inputs as of December 31, 2022 and June 30, 2023:


	December 31, 2022			June 30, 2023
Significant Unobservable Inputs	Input Range	Weighted Average		Input Range	Weighted Average
ULSD Gulf Coast Forward Curve	$2.35 - $2.59	$	2.48	$1.98 - $2.23	$	2.13
Historical Differential to PADD 3 Diesel	$0.88 - $1.62	$	1.13	$0.92 - $1.62	$	1.14
Historical Differential to PADD 5 Diesel	$1.91 - $3.05	$	2.31	$1.89 - $3.02	$	2.36

Convertible Promissory Note

In connection with the Company’s loan commitment to a certain equity method investee, the Company was issued a convertible promissory note with a principal balance equal to the amount of drawdown on the loan commitment (see Note 17). The convertible promissory note bears interest at 7% per annum, compounded quarterly, with a maturity date the earlier of May 7, 2024 or upon the occurrence of a triggering event such as change of control or an event of default. The convertible promissory note is classified as available-for-sale and is carried at fair value, which is measured using the income approach. Under the income approach, the Company used a DCF model in which cash flows anticipated over the term of the note are discounted to their present value using an expected discount rate. The discount rate used reflects the interest rates offered on loans of similar terms and to borrowers of similar credit quality, which are Level 3 inputs. As such, this valuation approach is considered a Level 3 fair value measurement.

The following table provides quantitative information about the significant inputs used to estimate the fair value of the convertible promissory note as of December 31, 2022 and June 30, 2023:



Significant Unobservable Inputs	December 31, 2022	June 30, 2023
Risk-free interest rate	4.57%	5.42%
Credit adjustment	8.36%	6.80%
Credit adjusted discount rate	12.93%	12.22%

The above significant unobservable inputs are subject to change based on changes in economic and market conditions. The use of significant unobservable inputs creates uncertainty in the measurement of fair value as of the reporting date. Significant increase or decrease in any of the inputs in isolation would result in a significantly lower or higher fair value measurement. Generally, a change in market interest rates is accompanied by a directionally opposite

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change in the estimated fair value of fixed-rate debt securities. The Company records changes in the fair value of available-for-sale debt securities in “Unrealized gain (loss) on available-for-sale securities” within other comprehensive income (loss) in the accompanying condensed consolidated statements of comprehensive loss.

There were no transfers of assets or liabilities between Level 1, Level 2, or Level 3 of the fair value hierarchy as of December 31, 2022 or June 30, 2023.

The following tables provide information by level for assets and liabilities that are measured at fair value on a recurring basis as of December 31, 2022 and June 30, 2023 (in thousands):


	December 31, 2022		Level 1		Level 2		Level 3
Assets:
Available-for-sale securities:
U.S. government securities ⁽¹⁾	$	64,880	$	64,880	$	—	$	—
Zero coupon bonds ⁽¹⁾		74,159		—		74,159		—
Convertible promissory note ⁽⁴⁾		1,880		—		—		1,880
Certificates of deposit ⁽¹⁾		530		—		530		—
Embedded derivatives ⁽³⁾		6,755		—		—		6,755
Liabilities:
Commodity swap contracts ⁽²⁾	$	3,845	$	—	$	—	$	3,845


	June 30, 2023		Level 1		Level 2		Level 3
Assets:
Available-for-sale securities:
U.S. government securities ⁽¹⁾	$	138,039	$	138,039	$	—	$	—
Convertible promissory note ⁽⁴⁾		4,295		—		—		4,295
Certificates of deposit ⁽¹⁾		530		—		530		—
Embedded derivatives ⁽³⁾		6,837		—		—		6,837
Liabilities:
Embedded derivatives ⁽³⁾		80		—		—		80
Commodity swap contracts ⁽²⁾	$	2,779	$	—	$	—	$	2,779

(1)	Included in “Short-term investments” in the accompanying condensed consolidated balance sheets. See Note 5 for more information.

(2)	Included in “Derivative liabilities, related party” and “Long-term portion of derivative liabilities, related party” as of December 31, 2022 and in “Derivative liabilities, related party” as of June 30, 2023 in the accompanying condensed consolidated balance sheets. See Note 6 for more information.

(3)

Included in “Prepaid expenses and other current assets” and “Notes receivable and other long-term assets, net” as of December 31, 2022 and in “Prepaid expenses and other current assets,” “Notes receivable and other long-term assets, net,” and “Accrued liabilities” as of June 30, 2023 in the accompanying condensed consolidated balance sheets. See Note 6 for more information.

(4)	Included in “Notes receivable and other long-term assets, net” as of December 31, 2022 and in “Other receivables” as of June 30, 2023 in the accompanying condensed consolidated balance sheets.

The following table provides a reconciliation of the beginning and ending balances of items measured at fair value on a recurring basis as shown in the tables above that used significant unobservable inputs (Level 3), as well as the change in unrealized gains or losses for the periods included in earnings or other comprehensive income (loss) (in thousands):

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	Assets:		Assets:		Assets:		Liabilities:		Liabilities:
	Commodity		Embedded		Convertible		Commodity		Embedded
	Swap Contracts		Derivatives		Promissory Note		Swap Contracts		Derivatives
Balance as of March 31, 2022	$	—	$	9,923	$	—	$	(8,566)	$	—
Settlements, net		—		—		—		2,622		—
Total gain (loss)		—		1,422		—		(5,090)		(32)
Balance as of June 30, 2022	$	—	$	11,345	$	—	$	(11,034)	$	(32)

Balance as of March 31, 2023	$	—	$	4,949	$	3,048	$	(3,875)	$	(696)
Settlements, net		—		—		—		1,441		—
Total gain (loss)		—		1,888		889		(345)		616
Purchases		—		—		1,268		—		—
Equity method investment loss		—		—		(910)		—		—
Balance as of June 30, 2023	$	—	$	6,837	$	4,295	$	(2,779)	$	(80)

Change in unrealized gain (loss) for the three months ended June 30, 2022 included in earnings	$	—	$	1,422	$	—	$	(2,468)	$	(32)
Change in unrealized gain (loss) for the three months ended June 30, 2023 included in earnings	$	—	$	1,888	$	—	$	1,096	$	616
Change in unrealized gain (loss) for the three months ended June 30, 2023 included in other comprehensive income (loss)	$	—	$	—	$	889	$	—	$	—


	Assets:		Assets:		Assets:		Liabilities:		Liabilities:
	Commodity		Embedded		Convertible		Commodity		Embedded
	Swap Contracts		Derivatives		Promissory Note		Swap Contracts		Derivatives
Balance as of December 31, 2021	$	—	$	6,776	$	—	$	(4,383)	$	—
Settlements, net		—		—		—		3,901		—
Total gain (loss)		—		4,569		—		(10,552)		(32)
Balance as of June 30, 2022	$	—	$	11,345	$	—	$	(11,034)	$	(32)

Balance as of December 31, 2022	$	—	$	6,755	$	1,880	$	(3,845)	$	—
Settlements, net		(1,424)		—		—		2,456		—
Total gain (loss)		1,424		82		1,105		(1,390)		(80)
Purchases		—		—		2,478		—		—
Equity method investment loss		—		—		(1,168)		—		—
Balance as of June 30, 2023	$	—	$	6,837	$	4,295	$	(2,779)	$	(80)

Change in unrealized gain (loss) for the six months ended June 30, 2022 included in earnings	$	—	$	4,569	$	—	$	(6,651)	$	(32)
Change in unrealized gain (loss) for the six months ended June 30, 2023 included in earnings	$	—	$	82	$	—	$	1,066	$	(80)
Change in unrealized gain (loss) for the six months ended June 30, 2023 included in other comprehensive income (loss)	$	—	$	—	$	1,105	$	—	$	—

Other Financial Assets and Liabilities

The carrying amounts of the Company’s cash, cash equivalents, receivables and payables approximate fair value due to the short-term nature of those instruments. The carrying amounts of the Company’s debt instruments approximated their respective fair values as of December 31, 2022 and June 30, 2023. The fair values of these debt instruments were estimated using a DCF analysis based on interest rates offered on loans with similar terms to borrowers of similar credit quality, which are Level 3 inputs. See Note 12 for more information about the Company’s debt instruments.

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Note 8—Other Receivables

Other receivables as of December 31, 2022 and June 30, 2023 consisted of the following (in thousands):


	December 31,		June 30,
	2022		2023
Loans to customers to finance vehicle purchases	$	523	$	422
Accrued customer billings		4,910		7,489
Fuel tax credits		9,462		7,376
Other		2,131		11,801
Total other receivables	$	17,026	$	27,088

Note 9—Inventory

Inventory consists of raw materials and spare parts, work in process and finished goods and is stated at the lower of cost (first-in, first-out) or net realizable value. The Company evaluates inventory balances for excess quantities and obsolescence by analyzing estimated demand, inventory on hand, sales levels and other information and reduces inventory balances to net realizable value for excess and obsolete inventory based on this analysis.

Inventory as of December 31, 2022 and June 30, 2023 consisted of the following (in thousands):


	December 31,		June 30,
	2022		2023
Raw materials and spare parts	$	37,144	$	38,517
Total inventory	$	37,144	$	38,517

Note 10—Land, Property and Equipment

Land, property and equipment, net as of December 31, 2022 and June 30, 2023 consisted of the following (in thousands):


	December 31,		June 30,
	2022		2023
Land	$	3,476	$	3,620
LNG liquefaction plants		94,790		96,607
Station equipment		353,104		379,272
Trailers		73,253		72,553
Other equipment		106,184		99,795
Construction in progress		91,105		117,921
		721,912		769,768
Less accumulated depreciation		(457,844)		(477,305)
Total land, property and equipment, net	$	264,068	$	292,463

Included in “Land, property and equipment, net” are capitalized software costs of $35.3 million and $35.8 million as of December 31, 2022 and June 30, 2023, respectively. Accumulated amortization of the capitalized software costs are $32.1 million and $33.0 million as of December 31, 2022 and June 30, 2023, respectively.

The Company recorded amortization expense related to capitalized software costs of $0.3 million and $0.5 million in the three months ended June 30, 2022 and 2023, respectively, and $0.6 million and $0.9 million in the six months ended June 30, 2022 and 2023, respectively.

As of December 31, 2022 and June 30, 2023, $12.9 million and $12.7 million, respectively, are included in “Accounts payable” and “Accrued liabilities” in the accompanying condensed consolidated balance sheets, representing

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amounts related to purchases of property and equipment. These amounts are excluded from the accompanying condensed consolidated statements of cash flows as they are non-cash investing activities.

Fueling Station Equipment Removal

The Company was requested by Pilot Travel Centers LLC (“Pilot”) to remove station equipment at select Pilot locations to accommodate Pilot making physical changes to the premises, which required the removal of the Company’s station equipment. The premises where the affected fueling stations are located were secured by long-term lease agreements between Pilot and the Company pursuant to which the Company had contractual rights to operate its fueling stations until the expiration of the respective leases. However, in July 2022, the Company entered into an amendment (the “Amendment”) to the Liquefied Natural Gas Fueling Station and LNG Master Sales Agreement between Pilot and Clean Energy, dated August 2, 2010, to decommission and remove station equipment from the premises where the affected fueling stations are located in accordance with a phased removal schedule beginning in the third quarter of 2022. In April 2023, Pilot and the Company agreed to extend the removal completion deadline to provide the Company additional time to obtain the required permits and to complete the decommissioning activities. As of June 30, 2023, removal and decommissioning activities were in progress at two remaining Pilot locations.

Note 11—Accrued Liabilities

Accrued liabilities as of December 31, 2022 and June 30, 2023 consisted of the following (in thousands):


	December 31,		June 30,
	2022		2023
Accrued alternative fuels incentives ⁽¹⁾	$	34,239	$	31,993
Accrued employee benefits		5,128		4,863
Accrued gas and equipment purchases		22,008		13,480
Accrued interest		1,827		1,616
Accrued property and other taxes		3,782		3,525
Accrued salaries and wages		6,857		5,326
Embedded derivatives		—		80
Other ⁽²⁾		16,238		15,726
Total accrued liabilities	$	90,079	$	76,609

(1)	Includes amount for RINs, LCFS Credits, and AFTC payable to third parties.

(2)	No individual item in “Other” exceeds 5% of total current liabilities.

Note 12—Debt

Debt obligations as of December 31, 2022 and June 30, 2023 consisted of the following (in thousands):


	December 31, 2022
			Unamortized Debt		Balance, Net of
	Principal Balance		Financing Costs		Financing Costs
Riverstone term loan	$	150,000	$	4,529	$	145,471
Other debt		93		—		93
Total debt		150,093		4,529		145,564
Less amounts due within one year		(93)		—		(93)
Total long-term debt	$	150,000	$	4,529	$	145,471

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	June 30, 2023
			Unamortized Debt		Balance, Net of
	Principal Balance		Financing Costs		Financing Costs
Riverstone term loan	$	150,000	$	5,380	$	144,620
Other debt		255		—		255
Total debt		150,255		5,380		144,875
Less amounts due within one year		(38)		—		(38)
Total long-term debt	$	150,217	$	5,380	$	144,837

Riverstone Credit Agreement

On December 22, 2022 (the “Closing Date”), the Company entered into a Senior Secured First Lien Term Loan Credit Agreement (the “Riverstone Credit Agreement”) with a syndicate of lenders. Pursuant to the Riverstone Credit Agreement, the lenders made a $150,000,000 sustainability-linked senior secured term loan (the “Sustainability-Linked Term Loan”) to the Company, a transaction aligned with the five pillars of the Loan Syndications and Trading Association’s sustainability-linked loan principles. Payments for the Sustainability-Linked Term Loan are interest only with a balloon principal payment due on the maturity date, which is December 22, 2026. The Sustainability-Linked Term Loan bears interest, at the option of the Company, at (a) Adjusted Term SOFR or (b) the Alternate Base Rate (“ABR”), which is defined as the greater of (i) the Prime Rate, (ii) the Federal Funds Effective Rate plus 0.50%, and (iii) one-month Adjusted Term SOFR plus 1.00%, plus an applicable margin of 6.50% for interest rate based on SOFR or 5.50% for election under the ABR through the second anniversary of the Closing Date. After the second anniversary of the Closing Date, the applicable margin increases to 7.25% for election under SOFR or 6.25% for election under the ABR. The applicable margin is subject to a sustainability rate adjustment feature, which may increase the applicable margin by 25 basis points if certain KPI metric is not met for fiscal years beginning after December 31, 2024. The sustainability rate adjustment feature shall be applied retroactively to commence as of December 31, 2025. Interest rate for the Sustainability-Linked Term Loan has an interest rate floor of 1.50% for election under SOFR and 2.50% for election under the ABR. Proceeds from the Sustainability-Linked Term Loan were or will be used to repay certain existing indebtedness of the Company, to finance permitted investments from time to time, to pay transaction costs related to the Riverstone Credit Agreement and for other general corporate purposes. In connection with the Sustainability-Linked Term Loan, the Company is obligated to pay other facility fees customary for credit facilities of similar size and type.

The Company has the option to prepay all or any portion of the amounts owed prior to the maturity date and is subject to customary mandatory prepayments clauses. All prepayments and all other payments of the Sustainability-Linked Term Loan principal are subject to a call premium (2.0% from the one-year anniversary of the Closing Date to the date that is eighteen months after the Closing Date, 2.5% after the date that is eighteen months after the Closing Date to the date that is twenty-four months after the Closing Date, and 3% at any time thereafter). No call premium applies to any prepayment of the Sustainability-Linked Term Loan made prior to the first anniversary of the Closing Date. In conjunction with the Riverstone Credit Agreement, the Company and certain of its subsidiaries entered into a Guarantee and Collateral Agreement (the “Security Agreement”) in favor of the lenders. Under the Security Agreement, the Company and certain of its subsidiaries granted the lenders a security interest in substantially all of their personal property, rights and assets as collateral for the Sustainability-Linked Term Loan under the Riverstone Credit Agreement. The Company and certain of its subsidiaries also agreed to grant a security interest in certain of their material real property interests.

The Riverstone Credit Agreement contains customary representations, warranties, and affirmative and negative covenants, including compliance with certain financial ratios and liquidity test and limitation on the Company’s ability to incur additional indebtedness, make certain payments, and enter into certain transactions. Additionally, the Riverstone Credit Agreement includes a number of events of default clauses. If any event of default occurs (subject, in certain instances, to specified grace periods), the then outstanding principal, premium, if any, interest and any other monetary obligations under the Riverstone Credit Agreement may become due and payable immediately.

Other Debt

In May 2023, the Company entered into a sale and leaseback arrangement and received $0.3 million pursuant to the arrangement. The transaction did not qualify for sale and leaseback accounting due to a fixed price repurchase option

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that is not at fair value. As a result, the transaction was recorded under the financing method in which the assets remained on the accompanying condensed consolidated balance sheets, and the proceeds from the transaction were recorded as a financing liability. The sale and leaseback arrangement has a term of five years with interest and principal payable in 60 monthly installments at an annual effective rate of 13.38%. As of December 31, 2022 and June 30, 2023, the Company had other outstanding debt bearing interest at 4.75% and 13.38%, respectively.

Note 13—Net Income (Loss) Per Share

Basic net income (loss) per share is computed by dividing the net income (loss) attributable to Clean Energy Fuels Corp. by the weighted-average number of common shares outstanding and common shares issuable for little or no cash consideration during the period. Diluted net income (loss) per share is computed by dividing the net income (loss) attributable to Clean Energy Fuels Corp. by the weighted-average number of common shares outstanding and common shares issuable for little or no cash consideration during the period and potentially dilutive securities outstanding during the period, and therefore reflects the dilution from common shares that may be issued upon exercise or conversion of these potentially dilutive securities, such as stock options, warrants, convertible notes and restricted stock units. The dilutive effect of stock options and warrants is computed under the treasury stock method. The dilutive effect of convertible notes and restricted stock units is computed under the if-converted method. Potentially dilutive securities are excluded from the computations of diluted net income (loss) per share if their effect would be antidilutive.

The following table sets forth the computations of basic and diluted earnings (loss) per share for the three and six months ended June 30, 2022 and 2023 (in thousands except share and per share amounts):


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2023		2022		2023
Net loss attributable to Clean Energy Fuels Corp.	$	(13,235)	$	(16,301)	$	(37,426)	$	(54,998)

Weighted-average common shares outstanding		222,433,900		222,908,402		222,496,426		222,813,286
Dilutive effect of potential common shares from restricted stock units, stock options and stock warrants		—		—		—		—
Weighted-average common shares outstanding - diluted		222,433,900		222,908,402		222,496,426		222,813,286
Basic and diluted loss per share	$	(0.06)	$	(0.07)	$	(0.17)	$	(0.25)

The following potentially dilutive securities have been excluded from the diluted net loss per share calculations because their effect would have been antidilutive. Although these securities were antidilutive for these periods, they could be dilutive in future periods.


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2023		2022		2023
Stock options		16,410,764		18,154,864		16,410,764		18,154,864
Restricted stock units		680,191		367,145		680,191		367,145
Amazon warrant shares		58,767,714		58,767,714		58,767,714		58,767,714
Total		75,858,669		77,289,723		75,858,669		77,289,723

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Note 14—Stock-Based Compensation

The following table summarizes the compensation expense and related income tax benefit related to the Company’s stock-based compensation arrangements recognized in the accompanying condensed consolidated statements of operations during the three and six months ended June 30, 2022 and 2023 (in thousands):


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2022		2023		2022		2023
Stock-based compensation expense, net of $0 tax in 2022 and 2023	$	6,468	$	6,093	$	14,721	$	12,189

As of June 30, 2023, there was $23.0 million of total unrecognized compensation costs related to unvested shares subject to outstanding service-based and market-based stock options and service-based restricted stock units. Unrecognized compensation costs associated with these stock-based awards are expected to be expensed over a weighted-average period of approximately 1.5 years. As of June 30, 2023, total unrecognized compensation costs related to unvested shares subject to outstanding performance-based stock options were $4.2 million.

Amazon Warrant

On April 16, 2021, the Company entered into a Project Addendum to Fuel Pricing Agreement (the “Fuel Agreement”) with Amazon Logistics, Inc., a subsidiary of Amazon.com, Inc. (“Amazon”), and a Transaction Agreement with Amazon (the “Transaction Agreement”), pursuant to which, among other things, the Company issued to Amazon.com NV Investment Holdings LLC, a subsidiary of Amazon (“Amazon Holdings”), a warrant to purchase up to an aggregate of 53,141,755 shares (the “Warrant Shares”) of the Company’s common stock at an exercise price of $13.49 per share. As a result of the issuance of additional shares of common stock under the Company’s at-the-market offering programs in 2021 and in accordance with the terms of the warrant, on June 14, 2021, the number of shares of the Company’s common stock that may be purchased pursuant to the warrant, at an exercise price of $13.49 per share, increased by an aggregate of 5,625,959 shares (the “Additional Warrant Shares”).

The Warrant Shares and the Additional Warrant Shares shall vest in multiple tranches, certain of which vested immediately upon execution of the Fuel Agreement. Subsequent tranches will vest over time based on fuel purchases by Amazon and its affiliates, up to a total of $500.0 million, excluding any payments attributable to “Pass Through Costs,” which consist of all costs associated with the delivered cost of gas and applicable taxes determined by reference to the selling price of gallons or gas sold. The right to exercise the warrants and to receive the Warrant Shares and Additional Warrant Shares (the “Amazon Warrant”) that have vested expires on April 16, 2031.

Non-cash stock-based sales incentive contra-revenue charges (“Amazon Warrant Charges”) associated with the Amazon Warrant are recognized as Amazon and its affiliates purchase fuel and vesting conditions become probable of being achieved, based on the grant date fair value of the Amazon Warrant.

The following table summarizes the Amazon Warrant activity for the six months ended June 30, 2023:


		Warrant
		Shares
Outstanding and unvested as of December 31, 2022		42,314,667
Granted		—
Vested		(1,763,112)
Outstanding and unvested as of June 30, 2023		40,551,555

1,763,112 shares of the Amazon Warrant vested in the six months ended June 30, 2023 based on fuel purchases made by Amazon and its affiliates. The Company recognized Amazon Warrant Charges of $4.8 million and $13.9 million in the three months ended June 30, 2022 and 2023, respectively, and $8.5 million and $27.7 million in the six months ended June 30, 2022 and 2023, respectively, relating to customer fuel purchases. As of December 31, 2022 and June 30,

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2023, the Company had a customer incentive asset of $22.2 million and $10.6 million, respectively, classified in “Prepaid expenses and other current assets” in the accompanying condensed consolidated balance sheets.

Note 15—Stockholders’ Equity

Authorized Shares

On June 14, 2021, the Company’s stockholders approved an increase in the number of shares of common stock the Company is authorized to issue from 304,000,000 to 454,000,000. As of June 30, 2023, the Company is authorized to issue 455,000,000 shares, of which 454,000,000 shares of capital stock are designated common stock and 1,000,000 shares are designated preferred stock.

Share Repurchase Program

On March 12, 2020, the Company’s Board of Directors approved a share repurchase program of up to $30.0 million (exclusive of fees and commissions) of the Company’s outstanding common stock (the “Repurchase Program”). On December 7, 2021, the Company’s Board of Directors approved an increase in the aggregate purchase amount under the Repurchase Program from $30.0 million to $50.0 million (exclusive of fees and commissions). The Repurchase Program does not have an expiration date, and it may be suspended or discontinued at any time. As of June 30, 2023, the Company has utilized a total of $23.5 million under the Repurchase Program from its inception to repurchase 9,387,340 shares of common stock, and a total of $26.5 million of authorized funds remain available for common stock repurchase under the Repurchase Program. The Repurchase Program does not obligate the Company to acquire any specific number of shares. Repurchases under the Repurchase Program may be effected from time to time through open market purchases, privately negotiated transactions, structured or derivative transactions, including accelerated share repurchase transactions, or other methods of acquiring shares, in each case subject to market conditions, applicable securities laws and other relevant factors. Repurchases may also be made under plans complying with Rule 10b5-1 under the Securities Exchange Act of 1934, as amended.

Note 16—Income Taxes

The provision for income taxes for interim periods is determined using an estimate of the Company’s annual effective tax rate, adjusted for discrete items, if any, that are taken into account in the relevant period. Each quarter, the Company updates the estimate of the annual effective tax rate, and if the estimated tax rate changes, a cumulative adjustment is recorded.

The Company recorded an income tax expense of $0.1 million in the three months ended June 30, 2022 and an income tax benefit of $0.1 million in the three months ended June 30, 2023. The Company recorded an income tax expense of $0.1 million in the six months ended June 30, 2022 and an income tax benefit of $0.1 million in the six months ended June 30, 2023. Income tax expense in both periods are related to the Company’s U.S. and foreign operations. The effective tax rates for the three and six months ended June 30, 2022 and 2023 are different from the federal statutory tax rate primarily due to losses for which no tax benefit has been recognized.

The Company increased its unrecognized tax benefits in the six months ended June 30, 2023 by $2.3 million. This increase is primarily attributable to the portion of AFTC revenue recognized in the period attributed to the federal fuel tax the Company collected from its customers and deductions attributed to the unvested Amazon Warrant during the six months ended June 30, 2023. The net interest incurred was immaterial for the three and six months ended June 30, 2022 and 2023.

On August 16, 2022, the Inflation Reduction Act of 2022 (the “IRA”) was signed into law. The IRA offers significant tax incentives targeting energy transaction and renewables:

●

Alternative Fuel Tax Credit (“AFTC”) is reinstated to apply retroactively to fuel sales transactions from January 1, 2022 through December 31, 2024.

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●

The investment tax credit under Section 48 of the Internal Revenue Code is expanded to include Qualified Biogas Property placed in service after December 31, 2022. The rate of this credit is 6% at base level and increased to 30% if the prevailing wages and apprenticeship requirements are met. Further, this credit is transferrable to an unrelated party. The Company expects the credit to bring significant cash flow for the Renewable Natural Gas projects that it has invested and will invest through year 2024.

●

A new tax credit under Section 45Z of the Internal Revenue Code is introduced to apply to transportation fuel produced and sold by the taxpayer from January 1, 2025 through December 31, 2027. The bonus credit is $1.00/gallon multiplied by an applicable emissions factor but would be reduced to $0.20/gallon ($0.35/gallon for sustainable aviation fuel) if prevailing wage and apprenticeship requirements are not met. Given the negative carbon intensity (“CI”) score for renewable natural gas, the Company expects that the Renewable Natural Gas projects will be eligible for this credit at a rate greater than $1.00/gallon of fuel sold.

●

The alternative fuel refueling property credit under Section 30C of the Internal Revenue Code was reinstated for 2022 and extended an additional 10 years to apply to any property placed in service before January 1, 2033. For business property, the credit amount decreases to 6% (from 30%) with a maximum amount of $100,000 per item (previously $30,000 per location per year). Business property meeting prevailing wage and registered apprenticeship requirements may be eligible for a credit amount of 30% ($100,000 maximum).

The Internal Revenue Service and Treasury have been issuing regulations or other guidance that clarify how these credits will be eligible and calculated. The Company will continue to evaluate the impact of the IRA as additional information becomes available.

Note 17—Commitments and Contingencies

Environmental Matters

The Company is subject to federal, state, local and foreign environmental laws and regulations. The Company does not anticipate any expenditures to comply with such laws and regulations that would have a material effect on the Company’s consolidated financial position, results of operations or liquidity. The Company believes that its operations comply, in all material respects, with applicable federal, state, local and foreign environmental laws and regulations.

Litigation, Claims and Contingencies

The Company may become party to various legal actions that arise in the ordinary course of its business. The Company is also subject to audit by tax and other authorities for varying periods in various federal, state, local and foreign jurisdictions, and disputes may arise during the course of these audits. It is impossible to determine the ultimate liabilities that the Company may incur resulting from any of these lawsuits, claims, proceedings, audits, commitments, contingencies and related matters or the timing of these liabilities, if any. If these matters were to ultimately be resolved unfavorably, it is possible that such an outcome could have a material adverse effect upon the Company’s consolidated financial position, results of operations, or liquidity. The Company does not, however, anticipate such an outcome and believes the ultimate resolution of these matters will not have a material adverse effect on the Company’s consolidated financial position, results of operations, or liquidity.

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Long-Term Take-or-Pay Natural Gas Purchase Contracts

The Company has entered into quarterly fixed price natural gas purchase contracts with take-or-pay commitments extending through June 2024. As of June 30, 2023, the fixed commitments under these contracts totaled approximately $1.7 million for the remainder of the year ending December 31, 2023 and $2.0 million for the year ending December 31, 2024.

Loan Commitment to an Equity Method Investee

In November 2022, the Company entered into a Note Purchase Agreement with a certain equity method investee. Pursuant to the Note Purchase Agreement, the Company irrevocably committed to make available up to $5.5 million in delayed draw loans to fund the investee’s working capital requirements. In exchange, the Company received a convertible promissory note with a principal balance equal to the total amount of drawdown on the loan commitment. The convertible promissory note carries an interest rate equal to 7% per annum, compounded quarterly, and is due and payable in May 2024, subject to certain, specified prepayment clauses.

Note 18—Leases

Lessor Accounting

The Company leases fueling station equipment to customers pursuant to agreements that contain an option to extend and an end-of-term purchase option. Receivables from these leases are accounted for as finance leases, specifically sales-type leases, and are included in “Other receivables” and “Notes receivable and other long-term assets, net” in the accompanying condensed consolidated balance sheets.

The Company recognizes the net investment in the lease as the sum of the lease receivable and the unguaranteed residual value, both of which are measured at the present value using the interest rate implicit in the lease.

During each of the three months ended June 30, 2022 and 2023, the Company recognized $0.1 million in “Interest income” on its lease receivables. During each of the six months ended June 30, 2022 and 2023, the Company recognized $0.2 million in “Interest income” on its lease receivables.

The following schedule represents the Company’s maturities of lease receivables as of June 30, 2023 (in thousands):


Fiscal year:
Remainder of 2023	$	481
2024		962
2025		962
2026		985
2027		1,105
Thereafter		1,218
Total minimum lease payments		5,713
Less amount representing interest		(1,260)
Present value of lease receivables	$	4,453

Note 19—Alternative Fuel Excise Tax Credit

Under separate pieces of U.S. federal legislation, the Company was eligible to receive AFTC for its natural gas vehicle fuel sales made between October 1, 2006 and December 31, 2021. In August 2022, the Inflation Reduction Act of 2022 was enacted, extending AFTC for an additional three years through December 31, 2024, beginning retroactively to January 1, 2022. The AFTC incentive in the extension period under the Inflation Reduction Act of 2022 is equal to $0.50 per gasoline gallon equivalent of CNG and $0.50 per diesel gallon of LNG that the Company sells as vehicle fuel.

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Based on the service relationship with its customers, either the Company or its customers claim the credit. The Company records its AFTC, if any, as revenue in its condensed consolidated statements of operations because the credits are fully payable to the Company and do not offset income tax liabilities. As such, the credits are not deemed income tax credits under the accounting guidance applicable to income taxes.

Note 20—Related Party Transactions

TotalEnergies S.E.

In the three and six months ended June 30, 2022, the Company recognized revenue of $1.5 million and $2.9 million, respectively, relating to equipment lease revenue and LNG sold to TotalEnergies and its affiliates in the ordinary course of business. In the six months ended June 30, 2023, the Company recognized revenue of $1.4 million relating to RINs and LNG sold to TotalEnergies and its affiliates in the ordinary course of business, equipment lease revenue, AFTCs, and settlements on commodity swap contracts (Note 6). Revenue recognized in the three months ended June 30, 2023 was immaterial. As of December 31, 2022, the Company had receivables from TotalEnergies of $2.5 million. Outstanding receivables due from TotalEnergies were immaterial as of June 30, 2023.

In the three and six months ended June 30, 2022, the Company paid TotalEnergies $2.8 million and $3.6 million, respectively, for expenses incurred in the ordinary course of business, settlements on commodity swap contracts (Note 6), and the guaranty fee under the Credit Support Agreement with TotalEnergies Holdings USA Inc., a wholly owned subsidiary of TotalEnergies. In the three and six months ended June 30, 2023, the Company paid TotalEnergies $1.8 million and $2.5 million, respectively, for expenses incurred in the ordinary course of business and for settlements on commodity swap contracts (Note 6). As of December 31, 2022, total payables due to TotalEnergies was $0.2 million. Total payables due to TotalEnergies were immaterial as of June 30, 2023.

SAFE&CEC S.r.l.

In the three and six months ended June 30, 2022, the Company received $0.1 million and $0.1 million, respectively, from SAFE&CEC S.r.l. in the ordinary course of business. In the three and six months ended June 30, 2023, the Company received $0.1 million and $0.3 million, respectively, from SAFE&CEC S.r.l. in the ordinary course of business. As of December 31, 2022 and June 30, 2023, the Company had receivables due from SAFE&CEC S.r.l. of $0.3 million and $0.1 million, respectively.

In the three and six months ended June 30, 2022, the Company paid SAFE&CEC S.r.l. $1.6 million and $5.7 million, respectively, for parts and equipment in the ordinary course of business. In the three and six months ended June 30, 2023, the Company paid SAFE&CEC S.r.l. $6.2 million and $9.2 million, respectively, for parts and equipment in the ordinary course of business. As of December 31, 2022 and June 30, 2023, the Company had payables due to SAFE&CEC S.r.l. of $3.3 million and $4.3 million, respectively.

TotalEnergies Joint Venture(s) and bpJV

Pursuant to the TotalEnergies JV Agreement and the bp JV Agreement, the Company manages the day-to-day operations of RNG projects under the joint ventures in exchange for management fees. In the three and six months ended June 30, 2022, the Company recognized management fee revenue of $0.3 million and $0.6 million, respectively. In the three and six months ended June 30, 2023, the Company recognized management fee revenue of $0.5 million and $0.9 million, respectively. As of December 31, 2022 and June 30, 2023, the Company had management fees receivable due from the joint ventures with TotalEnergies and bp of $0.5 million and $0.2 million, respectively.

In the three and six months ended June 30, 2022, the Company paid $0.1 million and $0.2 million, respectively, on behalf of the joint ventures for costs incurred in the ordinary course of business. In the three and six months ended June 30, 2023, the Company paid $0.8 million and $1.2 million, respectively, on behalf of the joint ventures for costs incurred in the ordinary course of business. As of December 31, 2022 and June 30, 2023, the Company had receivables due from

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the joint ventures with TotalEnergies and bp of $0.6 million and $0.2 million, respectively, representing outstanding unreimbursed costs that the Company paid on behalf of the joint ventures.

In connection with the capital call issued by the DR JV on June 28, 2023, the Company advanced $5.5 million to the DR JV. Proceeds from the advance were used to fund required loan reserves and to paydown outstanding liabilities of the DR JV (see Note 3). As of June 30, 2023, the Company had a receivable due from the DR JV of $5.5 million, which is expected to be paid by the DR JV before the end of 2023.

Other Equity Method Investees

Pursuant to the Note Purchase Agreement, in the three and six months ended June 30, 2023, the Company provided $1.2 million and $2.3 million, respectively, to a certain equity method investee in connection with the loan commitment (see Note 17). As of December 31, 2022 and June 30, 2023, the carrying amount of the Company’s convertible promissory note measured at fair value was $1.9 million and $4.3 million, respectively, and is included in “Notes receivable and other long-term assets, net” as of December 31, 2022 and in “Other receivables” as of June 30, 2023 in the accompanying condensed consolidated balance sheets.

In the three and six months ended June 30, 2023, the Company recognized management fee revenue of $0.2 million and $0.3 million, respectively, relating to other equity method investees. No management fee revenue was recognized in the three and six months ended June 30, 2022. As of December 31, 2022 and June 30, 2023, the Company had management fees receivable due from other equity method investees of $0.1 million and $0.4 million, respectively.

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

The following Management’s Discussion and Analysis of Financial Condition and Results of Operations (this discussion, as well as discussions under the same heading in our other periodic reports, are referred to as the “MD&A”) should be read together with our unaudited condensed consolidated financial statements and the related notes included in this report, and all cross references to notes included in this MD&A refer to the identified note in such condensed consolidated financial statements. For additional context with which to understand our financial condition and results of operations, refer to the MD&A included in our Annual Report on Form 10-K for our fiscal year ended December 31, 2022, which was filed with the Securities and Exchange Commission (“SEC”) on February 28, 2023, as well as the audited consolidated financial statements and notes included therein (collectively, our “2022 Form 10-K”).

Cautionary Note Regarding Forward-Looking Statements

This MD&A and the other disclosures in this report contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Forward-looking statements are statements other than historical facts. These statements relate to future events or circumstances or our future performance, and they are based on our current assumptions, expectations and beliefs concerning future developments and their potential effect on our business. In some cases, you can identify forward-looking statements by the following words: “if,” “may,” “might,” “shall,” “will,” “can,” “could,” “would,” “should,” “expect,” “intend,” “plan,” “goal,” “objective,” “initiative,” “anticipate,” “believe,” “estimate,” “predict,” “project,” “forecast,” “potential,” “continue,” “ongoing” or the negative of these terms or other comparable terminology, although the absence of these words does not mean that a statement is not forward-looking. The forward-looking statements we make in this discussion include statements about, among other things, our future financial and operating performance, our growth strategies, including expectations regarding our delivery and sales of RNG and Environmental Credits (each as defined below), and anticipated trends in our industry and our business.

The preceding list is not intended to be an exhaustive list of all topics addressed by our forward-looking statements. Although the forward-looking statements we make reflect our good faith judgment based on available information, they are only predictions. Accordingly, our forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause our or our industry’s actual results, levels of activity, performance or achievements to be materially different from any future results, levels of activity, performance or achievements expressed or implied by these forward-looking statements. Factors that might cause or contribute to such differences include, among others, those discussed under “Risk Factors” in Part II, Item 1A of this report, as such factors may be amended, supplemented or superseded from time to time by other reports we file with the SEC. In addition, we operate in a competitive and rapidly evolving industry in which new risks emerge from time to time, and it is not possible for us to predict all of the risks we may face. Nor can we assess the effect of all factors on our business or the extent to which any factor or combination of factors could cause actual results to differ from our expectations. As a result of these and other potential risks and uncertainties, our forward-looking statements should not be relied on or viewed as guarantees of future events.

All of our forward-looking statements in this report are made only as of the date of this document and, except as required by law, we undertake no obligation to update publicly any forward-looking statements for any reason, including to conform these statements to actual results or to changes in our expectations. You should, however, review the factors and risks we describe in the reports we will file from time to time with the SEC for the most recent information about our forward-looking statements and the risks and uncertainties related to these statements. We qualify all of our forward-looking statements by this cautionary note.

Overview

We are North America’s leading provider of the cleanest fuel for the transportation market, based on the number of stations operated and the amount of gasoline gallon equivalents (“GGEs”) of renewable natural gas (“RNG”) and conventional natural gas sold. We calculate one GGE to equal 125,000 British Thermal Units (“BTUs”), and, as such, one million BTUs (“MMBTU”) equal eight GGEs. Through our sales of RNG, which is derived from biogenic methane produced by the breakdown of organic waste, we help thousands of vehicles, from airport shuttles to city buses to waste

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and heavy-duty trucks, reduce their amount of climate-harming greenhouse gas from 60% to over 400% based on determinations by the California Air Resources Board (“CARB”), depending on the source of the RNG, while also reducing criteria pollutants such as Nitrogen Oxides, or NOx. RNG is sold in the form of compressed natural gas (“CNG”) or liquefied natural gas (“LNG”).

As a clean energy solutions provider, we supply RNG and conventional natural gas both sourced from third party suppliers, in the form of CNG and LNG, for medium and heavy-duty vehicles; design and build, as well as operate and maintain (“O&M”), public and private vehicle fueling stations in the United States and Canada; develop and own dairy anaerobic digester gas (“ADG”) RNG production facilities; sell and service compressors and other equipment used in RNG production and at fueling stations; transport and sell RNG and conventional natural gas, in the form of CNG and LNG, via “virtual” natural gas pipelines and interconnects; sell U.S. federal, state and local government credits (collectively, “Environmental Credits”) we generate by selling RNG, in the form of CNG and LNG, as a vehicle fuel, including Renewable Identification Numbers (“RIN Credits” or “RINs”) under the federal Renewable Fuel Standard Phase 2 and credits under the California and the Oregon Low Carbon Fuel Standards (collectively, “LCFS Credits”); and obtain federal, state and local tax credits, grants and incentives.

At present, we see the best use of RNG as a replacement for fossil-based fuel in the transportation sector. We believe the most attractive market for RNG is U.S. heavy-duty Class 8 trucking, and, based on information from the American Trucking Association and our own internal estimates, we believe there are approximately 4.1 million Class 8 heavy-duty trucks operating in the U.S. that use over 40 billion gallons of fuel per year. We deliver RNG to the transportation market through 576 fueling stations we own, operate or supply in 43 states and the District of Columbia in the U.S., including over 200 stations in California. We also own, operate, or supply 24 fueling stations in Canada.

Critically, to generate the valuable Environmental Credits, RNG must be placed in vehicle fuel tanks. We believe our stations and customer relationships allow us to deliver substantially more RNG to vehicle operators than any other participant in the market – we calculate that we have access to more fueling stations and vehicle fleets than all our competitors combined. As of June 30, 2023, we served over 1,000 fleet customers operating over 50,000 vehicles on our fuels.

Longer term, we plan to expand availability of hydrogen fuel for vehicle fleets. As operators deploy more hydrogen powered vehicles, we can modify our fueling stations to reform our RNG and deliver clean hydrogen to customers. We also believe our RNG can be used to generate clean electricity to power electric vehicles, and we have the capability to add electric vehicle charging at our station sites, although the cost of adding electric vehicle charging capacity may be significant.

Impact of COVID-19, Inflation, Labor Shortage, Material Availability and Interest Rate

The COVID-19 pandemic had an adverse effect on the volume of our sales, which we saw bottom in the second quarter of 2020. The subsequent surge in cases driven by the omicron variant negatively affected the demand recovery for our vehicle fuels in the first quarter of 2022. Since that time, we have seen improvement in volumes in all customer markets, and the residual effects of the COVID-19 pandemic have not been a significant headwind to our business operations. For more information, see “Risk Factors” in Part II, Item 1A of this report.

In recent periods, we have experienced increases in commodity and supply chain costs due to inflationary pressures. Additionally, effects stemming from the COVID-19 pandemic have caused disruptions in labor supply and in supply chains, leading to shortages of certain materials and equipment and higher labor costs. The future duration and extent of these pressures and effects are difficult to predict. Although we have partially offset these increased costs through price increases for our products and services, our efforts to manage the current inflationary pressure and to recover inflation-based cost increases from our customers may be hampered by the structure of our contracts as well as the competitive and economic conditions of the markets in which we serve. For more information, see “Risk Factors” in Part II, Item 1A of this report.

The majority of our debt outstanding represents a sustainability-linked term loan bearing variable rates of interest. Changes in market interest rates will affect the interest expense incurred from this outstanding debt instrument, increasing

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or decreasing our interest expense in future periods. Furthermore, changes in market interest rates may affect the interest rate and corresponding interest expense on any new issuance of short-term and long-term debt securities. See “Quantitative and Qualitative Disclosures about Market Risk” in Part I, Item 3 of this report for more information.

Performance Overview

This performance overview discusses matters on which our management focuses in evaluating our financial condition and our operating results.

Sources of Revenue

The following table presents our sources of revenue:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
Revenue (in millions)	2022		2023		2022		2023
Product revenue⁽¹⁾:
Volume-related⁽²⁾
Fuel sales⁽³⁾	$	67.1	$	53.3	$	125.8	$	160.2
Change in fair value of derivative instruments⁽⁴⁾		(1.1)		3.6		(2.1)		1.1
RIN Credits		9.8		5.4		17.7		9.9
LCFS Credits		4.1		2.4		7.5		4.7
AFTC⁽⁵⁾		—		5.1		0.2		9.6
Total volume-related product revenue		79.9		69.8		149.1		185.5
Station construction sales		6.0		5.8		9.3		9.9
Total product revenue		85.9		75.6		158.4		195.4
Service revenue⁽⁶⁾:
Volume-related, O&M services		11.0		13.9		21.7		25.9
Other services		0.3		1.0		0.6		1.4
Total service revenue		11.3		14.9		22.3		27.3
Total revenue	$	97.2	$	90.5	$	180.7	$	222.7

(1)	A discussion of product revenue is included below under “Results of Operations.”

(2)

Our volume-related product revenue primarily consists of sales of RNG and conventional natural gas, in the form of CNG and LNG, and sales of RINs and LCFS Credits in addition to changes in fair value of our derivative instruments. More information about our GGEs of fuel sold in the periods is included below under “Key Operating Data,” and more information about our derivative instruments, which consist of commodity swap and customer fueling contracts, is included in Note 6.

(3)

Includes $4.8 million and $8.5 million of non-cash stock-based sales incentive contra-revenue charges related to the Amazon Warrant (as defined in Note 14) for the three and six months ended June 30, 2022, respectively. Includes $13.9 million and $27.7 million of non-cash stock-based sales incentive contra-revenue charges related to the Amazon Warrant (as defined in Note 14) for the three and six months ended June 30, 2023, respectively.

(4)

The change in fair value of derivative instruments is related to the Company’s commodity swap and customer fueling contracts. The amounts are classified as revenue because the Company’s commodity swap contracts are used to economically offset the risk associated with the diesel-to-natural gas price spread resulting from customer fueling contracts under the Company’s Zero Now truck financing program.

(5)	Represents the federal alternative fuel excise tax credit that we refer to as AFTC. AFTC is available for vehicle fuel sales made through December 31, 2024.

(6)

Our service revenue primarily represents sales from performance of O&M services. More information about our GGEs serviced in the periods relating to O&M services is included below under “Key Operating Data.” Additionally, a discussion of service revenue is included below under “Results of Operations.”

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Key Operating Data

In evaluating our operating performance, we focus primarily on: (1) the amount of total fuel volume we sell to our customers with particular focus on RNG volume as a subset of total fuel volume, (2) O&M services volume dispensed at facilities we do not own but where we provide O&M services on a per-gallon or fixed fee basis, (3) our station construction cost of sales, and (4) net income (loss) attributable to us. All RNG and conventional natural gas sold are currently sourced from third-party suppliers. The following tables present our key operating data for the years ended December 31, 2020, 2021 and 2022 and for the three and six months ended June 30, 2022 and 2023. Certain gallons are included in both fuel and service volumes when the Company sells fuel (product revenue) to a customer and provides maintenance services (service revenue) to the same customer.


	Year Ended						Three Months Ended				Six Months Ended
Fuel volume, GGEs⁽²⁾ sold (in millions),	December 31,						June 30,				June 30,
correlating to total volume-related product revenue	2020		2021		2022		2022		2023		2022		2023
RNG⁽¹⁾		153.3		167.0		198.2		50.0		58.6		89.7		112.0
Conventional natural gas⁽¹⁾		82.1		78.8		69.6		16.0		14.1		34.6		29.5
Total fuel volume		235.4		245.8		267.8		66.0		72.7		124.3		141.5

Year Ended

Three Months Ended

Six Months Ended

O&M services volume, GGEs⁽²⁾ serviced (in millions),

December 31,

June 30,

correlating to volume-related O&M services revenue

2020

2021

2022

2023

2022

2023

O&M services volume

218.4

229.8

240.4

60.5

65.9

116.1

125.5


	Year Ended						Three Months Ended				Six Months Ended
	December 31,						June 30,				June 30,
Other operating data (in millions)	2020		2021		2022		2022		2023		2022		2023
Station construction cost of sales	$	24.0	$	15.0	$	19.4	$	5.1	$	5.7	$	8.2	$	9.4
Net income (loss) attributable to Clean Energy Fuels Corp. ^{(3) (4) (5)}	$	(9.9)	$	(93.1)	$	(58.7)	$	(13.2)	$	(16.3)	$	(37.4)	$	(55.0)

(1)	All RNG and conventional natural gas sold were sourced from third-party suppliers.

(2)	GGEs are calculated based on the conversion rate of one MMBTU equaling eight GGEs.

(3)

Includes the following amounts of AFTC revenue: $19.8 million, $20.7 million and $21.8 million for the years ended December 31, 2020, 2021 and 2022, respectively, $0.0 million and $0.2 million for the three and six months ended June 30, 2022, respectively, $5.1 million and $9.6 million for the three and six months ended June 30, 2023, respectively.

(4)

Includes $83.6 million and $24.3 million of non-cash stock-based sales incentive contra-revenue charges relating to the Amazon Warrant for the years ended December 31, 2021 and 2022, respectively, and $4.8 million and $8.5 million for the three and six months ended June 30, 2022, respectively, and $13.9 million and $27.7 million for the three and six months ended June 30, 2023, respectively. No amounts of non-cash stock-based sales incentive contra-revenue charges relating to the Amazon Warrant were recorded for the year ended December 31, 2020.

(5)

Includes an unrealized gain (loss) from the change in fair value of commodity swap and customer fueling contracts of $2.1 million, $(3.5) million and $0.5 million for the years ended December 31, 2020, 2021 and 2022, respectively, and $(1.1) million and $3.6 million for the three months ended June 30, 2022 and 2023, respectively, and $(2.1) million and $1.1 million for the six months ended June 30, 2022 and 2023, respectively. See Note 6 for more information regarding the commodity swap and customer contracts.

2023 Developments

Winter 2022–2023 California Natural Gas Prices. From December 2022 to February 2023, the wholesale prices of natural gas in California spiked to historic levels. The January 2023 monthly index for Southern California settled at $54.31, and Henry Hub settled at $4.71, or 11.5 times higher than the industry benchmark index. December 2022 and February 2023 bookended the historic spike with the Southern California monthly index settled at $15.11 and $13.21, respectively, while Henry Hub settled at $6.71 and $3.11, respectively. These settlement prices reflect the monthly index established during the week leading up to the actual delivery month, also known as the bidweek. Drivers of the price increase were a combination of record below normal temperatures, production freeze-offs, pipeline maintenance, and an accelerated depletion of stored natural gas reserves. As a result, we experienced significantly higher gas supply costs,

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which affected our fueling stations in California in January 2023 and into February 2023. Although we have partially offset the increased costs through price increases from our customers, not all increased costs were recovered due to the competitive nature and market dynamics of the markets in which we serve. We estimate that the natural gas price spike in California from December 2022 to February 2023 resulted in a reduction in gross profit of approximately $10.0 million for the three months ended March 31, 2023. Since then, we have seen wholesale prices of natural gas in California largely revert to normal levels.

Tourmaline Joint Development. On April 18, 2023, we and Tourmaline Oil Corp. (“Tourmaline”) announced a CAD $70 million Joint Development Agreement to build and operate a network of CNG stations along key highway corridors across Western Canada. Under a 50-50 shared investment, we and Tourmaline expect to construct and commission up to 20 CNG fueling stations over the next five years, allowing heavy-duty trucks and other commercial transportation fleets that operate in the area to transition to the use of CNG, a lower carbon alternative to gasoline and diesel. On June 16, 2023, we entered into a Construction, Ownership and Operation Agreement with Tourmaline to jointly own and operate a CNG fueling station located in Edmonton, Alberta. Additional stations are expected in the municipalities of Calgary and Grande Prairie in Alberta and Kamloops in British Columbia.

South Fork Dairy Farm Incident. On April 10, 2023, an accident resulted in a fire at the South Fork Dairy farm in Dimmitt, Texas, the location of one of our 100% owned ADG RNG projects under development. The fire killed approximately 18,000 dairy cows and injured one person. Our partner, South Fork Dairy, plans to rebuild the dairy farm and to replenish the dairy cattle. At the time of the incident, we had not commenced onsite construction activities, and currently we are assessing the effects of this incident and expect a delay to the completion date of our ADG RNG project.

EPA Renewable Fuels Standard Update. On June 21, 2023, the Environmental Protection Agency (“EPA”) announced a final rule to establish the renewable volume obligation (RVO) for 2023 through 2025, increasing the RVO demand targets by an average of approximately 30% per year over the next three years. We believe this action by the EPA is constructive to the development and use of RNG as a low-carbon fuel for the transportation sector.

Business Risks and Uncertainties and Other Trends

Our business and prospects are exposed to numerous risks and uncertainties. For more information, see “Risk Factors” in Part II, Item 1A of this report. In addition, our performance in any period may be affected by various trends in our business and our industry, including certain seasonality trends. See the description of the key trends in our past performance and anticipated future trends included in the MD&A contained in our 2022 Form 10-K. Except as set forth below, and in “Impact of COVID-19, Inflation, Labor Shortage, Material Availability and Interest Rate” above, there have been no material changes to such trends as described in the MD&A contained in our 2022 Form 10-K.

The market for our vehicle fuels is a relatively new and developing market, and has experienced slow, volatile or unpredictable growth in many sectors. For example, to date, adoption and deployment of natural gas vehicles, both in general and in certain of our key customer markets, including heavy-duty trucking, have been slower than we anticipated. Slower growth may occur if the effects of the COVID-19 pandemic linger, as well as due to other unfavorable macroeconomic events, including inflationary pressures.

Market prices for RINs and LCFS Credits can be volatile and unpredictable, and the prices for such credits can be subject to significant fluctuations. The value of RINs and LCFS Credits (derived from market prices) can materially affect our revenue. Prices have fluctuated significantly during 2021, 2022 and into 2023 and will likely continue to be volatile. Further, LCFS Credit prices have fluctuated significantly during 2022 and into 2023 and will likely continue to be volatile.

The market price of our common stock can be volatile and unpredictable. If a decline of our market capitalization were sustained, we may need to perform goodwill impairment tests more frequently and it is possible that our goodwill could become impaired, which could result in material non-cash charges and adversely affect our results of operations.

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Debt Compliance

Certain of the agreements governing our outstanding debt, which are discussed in Note 12, have financial and non-financial covenants with which we must comply. As of June 30, 2023, we were in compliance with all of these covenants.

Risk Management Activities

Our risk management activities are discussed in the MD&A contained in our 2022 Form 10-K. During the six months ended June 30, 2023, there were no material changes to these activities.

Critical Accounting Policies and Estimates

The preparation of our condensed consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires the appropriate application of accounting policies, some of which require us to make estimates and assumptions that affect the amounts reported and related disclosures in our condensed consolidated financial statements. We base our estimates on historical experience and various assumptions that we believe are reasonable under the circumstances. To the extent there are differences between these estimates and actual results, our financial condition or results of operations could be materially affected.

Our critical accounting policies and the related judgments and estimates are discussed in the MD&A contained in our 2022 Form 10-K. There have been no material changes to our critical accounting policies as described in the MD&A contained in our 2022 Form 10-K.

Recently Adopted and Recently Issued Accounting Standards

See Note 1 for a description of recently adopted accounting standards and recently issued accounting standards pending adoption.

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Results of Operations

The table below presents, for each period indicated, each line item of our statements of operations data as a percentage of our total revenue for the period. Additionally, the narrative that follows provides a comparative discussion of certain of these line items between the periods indicated. Historical results are not indicative of the results to be expected in the current period or any future period.

Three Months Ended June 30, 2023 Compared to Three Months Ended June 30, 2022


	Three Months Ended
	June 30,
	2022		2023
Statements of Operations Data:
Revenue:
Product revenue	88.3	%	83.5	%
Service revenue	11.7		16.5
Total revenue	100.0		100.0
Operating expenses:
Cost of sales (exclusive of depreciation and amortization shown separately below):
Product cost of sales	67.8		61.4
Service cost of sales	6.3		9.5
Selling, general and administrative	27.2		31.5
Depreciation and amortization	10.9		12.0
Total operating expenses	112.2		114.4
Operating loss	(12.2)		(14.4)
Interest expense	(0.8)		(4.8)
Interest income	0.5		3.1
Other income, net	—		—
Loss from equity method investments	(1.2)		(2.1)
Loss before income taxes	(13.7)		(18.2)
Income tax (expense) benefit	(0.1)		0.1
Net loss	(13.8)		(18.1)
Loss attributable to noncontrolling interest	0.1		0.2
Net loss attributable to Clean Energy Fuels Corp.	(13.7)	%	(17.9)	%

Product revenue. Product revenue for the three months ended June 30, 2023 decreased by $10.3 million to $75.6 million, representing 83.5% of total revenue, compared to $85.9 million, representing 88.3% of total revenue, for the three months ended June 30, 2022. The decrease was primarily due to (1) lower average prices on fuel sold driven by a decrease in the prices of natural gas, partially offset by an increase in total GGEs of fuel sold, resulting in a $5.0 million decrease in product revenue from the prior year period, (2) a decrease in RIN revenue of $4.4 million resulting from lower average RIN prices in the second quarter of 2023 when compared to those in the same period of 2022, (3) a decrease in LCFS revenue of $1.6 million resulting from lower average LCFS prices in the second quarter of 2023 when compared to those in the same period of 2022, and (4) an increase of $9.1 million in non-cash stock-based sales incentive contra-revenue charges relating to the Amazon Warrant driven by higher customer fuel purchases. The decrease in product revenue between periods was partially offset by (1) an increase in AFTC revenue of $5.1 million as AFTC incentive was suspended in the three months ended June 30, 2022 and was not reinstated until August 2022 under the Inflation Reduction Act of 2022, and (2) a change in fair value of our commodity swap and customer contracts entered into in connection with our Zero Now truck financing program, as we recognized an unrealized gain of $3.6 million in the three months ended June 30, 2023 compared to an unrealized loss of $1.1 million in the same period of 2022.

Service revenue. Service revenue for the three months ended June 30, 2023 increased $3.6 million to $14.9 million, representing 16.5% of total revenue, compared to $11.3 million, representing 11.7% of total revenue, for the three months ended June 30, 2022. The increase was primarily due to an increase in GGEs serviced in the second quarter of 2023 compared to those in the same period of 2022.

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Product cost of sales. Product cost of sales for the three months ended June 30, 2023 decreased by $10.3 million to $55.6 million, representing 61.4% of total revenue, from $65.9 million, representing 67.8% of total revenue, in the three months ended June 30, 2022. The decrease was primarily due to lower natural gas prices, partially offset by an increase in GGEs of fuel sold and a $0.6 million increase in the cost of station construction activities.

Service cost of sales. Service cost of sales for the three months ended June 30, 2023 increased by $2.5 million to $8.6 million, representing 9.5% of total revenue, compared with $6.1 million or 6.3% of total revenue in the three months ended June 30, 2022. The increase was primarily due to an increase in GGEs serviced in the three months ended June 30, 2023 as compared to the same period in 2022.

Selling, general and administrative. Selling, general and administrative expenses increased by $2.0 million to $28.5 million in the three months ended June 30, 2023, from $26.5 million in the three months ended June 30, 2022. The increase was primarily driven by a $1.4 million increase in salaries and benefits as a result of higher headcount, a $0.5 million increase in recruiting and other professional fees, and a $0.5 million increase in general business, administrative and information technology expense. The increase was partially offset by a $0.4 million decrease in stock-based compensation expense due to vesting of equity awards granted in prior years, partially offset by equity awards granted in the current year.

Depreciation and amortization. Depreciation and amortization increased by $0.3 million to $10.9 million in the three months ended June 30, 2023, from $10.6 million in the three months ended June 30, 2022. The increase was primarily due to a higher amount of depreciable assets.

Interest expense. Interest expense increased by $3.7 million to $4.4 million in the three months ended June 30, 2023, from $0.7 million in the three months ended June 30, 2022, primarily due to higher outstanding indebtedness and higher average interest rates on outstanding indebtedness between periods.

Interest income. Interest income increased by $2.3 million to $2.8 million in the three months ended June 30, 2023, from $0.5 million in the three months ended June 30, 2022, primarily due to higher average interest rates between periods on the Company’s short-term investments.

Loss from equity method investments. Loss from equity method investments increased by $0.7 million to $1.9 million in the three months ended June 30, 2023, from $1.2 million in the three months ended June 30, 2022, primarily due to the operating results of SAFE&CEC S.r.l. and our joint venture(s) with TotalEnergies and bp.

Income tax expense (benefit). Income tax expense was $0.1 million for the three months ended June 30, 2022. We recognized an income tax benefit of $0.1 million for the three months ended June 30, 2023. Income tax expense and/or benefit is primarily related to deferred taxes associated with goodwill and the Company’s expected state tax expense.

Loss attributable to noncontrolling interest. During the three months ended June 30, 2022 and 2023, we recorded a gain of $0.1 million and $0.2 million, respectively, for the noncontrolling interest in the net loss of NG Advantage. The noncontrolling interest in NG Advantage represents a 6.7% minority interest that was held by third parties during both the 2022 and 2023 periods.

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Six Months Ended June 30, 2023 Compared to Six Months Ended June 30, 2022


	Six Months Ended
	June 30,
	2022		2023
Statements of Operations Data:
Revenue:
Product revenue	87.6	%	87.7	%
Service revenue	12.4		12.3
Total revenue	100.0		100.0
Operating expenses:
Cost of sales (exclusive of depreciation and amortization shown separately below):
Product cost of sales	68.4		78.7
Service cost of sales	7.1		7.3
Selling, general and administrative	30.1		26.1
Depreciation and amortization	12.1		9.7
Total operating expenses	117.7		121.8
Operating loss	(17.7)		(21.8)
Interest expense	(2.1)		(3.9)
Interest income	0.4		2.5
Other income, net	—		—
Loss from equity method investments	(1.6)		(1.7)
Loss before income taxes	(21.0)		(24.9)
Income tax (expense) benefit	(0.1)		0.1
Net loss	(21.1)		(24.8)
Loss attributable to noncontrolling interest	0.3		0.1
Net loss attributable to Clean Energy Fuels Corp.	(20.8)	%	(24.7)	%

Product revenue. Product revenue for the six months ended June 30, 2023 increased by $37.0 million to $195.4 million, representing 87.7% of total revenue, compared to $158.4 million, representing 87.6% of total revenue, for the six months ended June 30, 2022. The increase was primarily due to (1) higher average prices on fuel sold due in-part to the significant rise in prices of natural gas in California during January and February 2023 and an increase in total GGEs of fuel sold, resulting in $53.5 million increase in product revenue from the prior year period, (2) an increase in AFTC revenue of $9.3 million as AFTC incentive was suspended in the six months ended June 30, 2022 and was not reinstated until August 2022 under the Inflation Reduction Act of 2022, (3) an increase in station construction sales of $0.6 million due to increased construction activities, and (4) a change in fair value of our commodity swap and customer contracts entered into in connection with our Zero Now truck financing program, as we recognized an unrealized gain of $1.1 million in the six months ended June 30, 2023 compared to an unrealized loss of $2.1 million in the same period of 2022. The increase in product revenue between periods was partially offset by (1) a $19.1 million increase in non-cash stock-based sales incentive contra-revenue charges relating to the Amazon Warrant driven by higher customer fuel purchases, (2) a decrease in LCFS revenue of $2.7 million resulting from lower average LCFS prices in the first half of 2023 when compared to those in the same period of 2022, and (3) a decrease in RIN revenue of $7.8 million resulting from lower average RIN prices in the first half of 2023 when compared to those in the same period of 2022.

Service revenue. Service revenue for the six months ended June 30, 2023 increased $5.0 million to $27.3 million, representing 12.3% of total revenue, compared to $22.3 million, representing 12.4% of total revenue, for the six months ended June 30, 2022. The increase was primarily due to an increase in GGEs serviced in the first half of 2023 compared to those in the same period of 2022.

Product cost of sales. Product cost of sales for the six months ended June 30, 2023 increased by $51.7 million to $175.2 million, representing 78.7% of total revenue, from $123.5 million, representing 68.4% of total revenue, in the six months ended June 30, 2022. The increase was primarily due to an increase in natural gas prices driven in-part by the significant rise in cost of natural gas in California during January and February 2023, an increase in GGEs of fuel sold, and a $1.2 million increase in the cost of station construction activities.

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Service cost of sales. Service cost of sales for the six months ended June 30, 2023 increased by $3.5 million to $16.2 million, representing 7.3% of total revenue, compared with $12.7 million or 7.1% of total revenue in the six months ended June 30, 2022. The increase was primarily due to an increase in GGEs serviced in the six months ended June 30, 2023 as compared to the same period in 2022.

Selling, general and administrative. Selling, general and administrative expenses increased by $3.8 million to $58.2 million in the six months ended June 30, 2023, from $54.4 million in the six months ended June 30, 2022. The increase was primarily driven by a $3.5 million increase in salaries and benefits as a result of higher headcount, a $0.8 million increase in recruiting, legal and other professional fees, and a $2.0 million increase in general business, administrative and information technology expense. The increase was partially offset by a $2.5 million decrease in stock-based compensation expense due to vesting of equity awards granted in prior years, partially offset by equity awards granted in the current year.

Depreciation and amortization. Depreciation and amortization decreased by $0.3 million to $21.6 million in the six months ended June 30, 2023, from $21.9 million in the six months ended June 30, 2022. The decrease was primarily due to a lower amount of depreciable assets.

Interest expense. Interest expense increased by $4.9 million to $8.7 million in the six months ended June 30, 2023, from $3.8 million in the six months ended June 30, 2022, primarily due to higher outstanding indebtedness and higher average interest rates on outstanding indebtedness between periods.

Interest income. Interest income increased by $4.7 million to $5.5 million in the six months ended June 30, 2023, from $0.8 million in the six months ended June 30, 2022, primarily due to higher average interest rates between periods on the Company’s short-term investments.

Loss from equity method investments. Loss from equity method investments increased by $0.9 million to $3.8 million in the six months ended June 30, 2023, from $2.9 million in the six months ended June 30, 2022, primarily due to the operating results of SAFE&CEC S.r.l. and our joint venture(s) with TotalEnergies and bp.

Income tax expense (benefit). Income tax expense was $0.1 million for the six months ended June 30, 2022. We recognized an income tax benefit of $0.1 million for the six months ended June 30, 2023. Income tax expense and/or benefit is primarily related to deferred taxes associated with goodwill and the Company’s expected state tax expense.

Loss attributable to noncontrolling interest. During the six months ended June 30, 2022 and 2023, we recorded a gain of $0.5 million and $0.3 million, respectively, for the noncontrolling interest in the net loss of NG Advantage. The noncontrolling interest in NG Advantage represents a 6.7% minority interest that was held by third parties during both the 2022 and 2023 periods.

Liquidity and Capital Resources

Liquidity

Liquidity is the ability to meet present and future financial obligations through operating cash flows, the sale or maturity of investments or the acquisition of additional funds through capital management. Our financial position and liquidity are, and will continue to be, influenced by a variety of factors, including the level of our outstanding indebtedness and the principal and interest we are obligated to pay on our indebtedness; the amount and timing of any capital calls related to the joint venture(s) with TotalEnergies and/or bp, or any other joint venture we may enter into in the future; the amount and timing of any additional debt or equity financing we may pursue; our capital expenditure requirements; any merger, divestiture or acquisition activity; and our ability to generate cash flows from our operations. We expect cash provided by our operating activities to fluctuate as a result of a number of factors, including our operating results and the factors that affect these results, including the amount and timing of our vehicle fuel sales, station construction sales, sales of RINs and LCFS Credits and recognition of government credits, the continuing direct and indirect effects of the COVID-19 pandemic, grants and incentives, if any; fluctuations in commodity, station construction and labor costs; supply chain issues and unfavorable macroeconomic events, including inflationary pressures; environmental credit prices; variations in

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the fair value of certain of our derivative instruments that are recorded in revenue; and the amount and timing of our billing, collections and liability payments.

Cash Flows

Operating Activities. Cash used in operating activities was $7.0 million in the six months ended June 30, 2023, compared to cash provided by operating activities of $32.2 million in the comparable 2022 period. The decrease in cash provided by operating activities was primarily attributable to higher cash outlays for the procurement of natural gas in the six months ended June 30, 2023 as compared to the same period in 2022 and changes in working capital resulting from the timing of cash receipts, accruals, billings and payments of cash.

Investing Activities. Cash used in investing activities was $62.0 million in the six months ended June 30, 2023, compared to cash used in investing activities of $70.4 million in the comparable 2022 period. The decrease in cash used in investing activities was primarily attributable to a $46.1 million decrease in equity contributions to our joint ventures with bp and TotalEnergies, a $4.3 million decrease in net purchases of short-term investments in the six months ended June 30, 2023 when compared to the same period in 2022, a receipt of $1.9 million in grant proceeds, and a receipt of $1.2 million in connection with our joint collaboration with Tourmaline, partially offset by a $25.3 million increase in capital expenditures on property and equipment, a $10.2 million increase in outlay on RNG production projects and manure feedstock rights, a $5.9 million increase in net disbursements for loan receivables and advances.

Financing Activities. Cash used in financing activities was $2.2 million in the six months ended June 30, 2023, compared to $10.7 million used in financing activities in the comparable 2022 period. The decrease in cash used in financing activities was primarily attributable to lower principal repayments on outstanding indebtedness, no cash payments on debt extinguishment costs, and a decrease in cash outlays on repurchases of our common stock, partially offset by a decrease in cash proceeds from issuance of debt instruments and higher outlays on debt issuance fees relating to the Riverstone Credit Agreement.

Capital Expenditures, Indebtedness and Other Uses of Cash

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; additions or other modifications to existing fueling stations; RNG production facilities; debt repayments and repurchases; repurchases of common stock; purchases of heavy-duty trucks that use our fuels; additions or modifications of LNG 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; financing vehicles for our customers; 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.

Our business plan calls for approximately $90.0 million in capital expenditures in 2023. These capital expenditures primarily relate to the construction of fueling stations, IT software and equipment and LNG plant costs, and we expect to fund these expenditures primarily through cash on hand and cash generated from operations. Further, in 2023, we anticipate deploying up to approximately $40.0 million to develop ADG RNG production facilities. In 2022, we contributed $89.7 million to the bpJV.

We had total indebtedness, consisting of our debt and finance leases, of approximately $153.2 million in principal amount as of June 30, 2023, of which approximately $0.5 million, $1.6 million, $0.7 million, $150.3 million and $0.1 million is expected to become due in 2023, 2024, 2025, 2026 and 2027, respectively. Based on our outstanding indebtedness and applicable interest rates as of June 30, 2023, we expect our total interest payment obligations relating to our indebtedness to be approximately $17.9 million in 2023, $8.9 million of which had been paid when due as of June 30, 2023. We plan to and believe we are able to make all expected principal and interest payments in the next 12 months.

We also have indebtedness, including the amount representing interest, from our operating leases of approximately $109.4 million as of June 30, 2023, of which approximately $11.0 million, $10.3 million, $10.3 million,

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$10.2 million, $10.0 million and $57.6 million are expected to become due in 2023, 2024, 2025, 2026, 2027 and thereafter, respectively.

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. Although we believe we have sufficient liquidity and capital resources to repay our debt coming due in the next 12 months, we may elect to suspend, or limit repurchases under, our share repurchase program or pursue alternatives, such as refinancing, or debt or equity offerings, to increase our cash management flexibility.

Sources of Cash

Historically, our principal sources of liquidity have consisted of cash on hand; cash provided by our operations, including, if available, AFTC and other government credits, grants and incentives; cash provided by financing activities; and sales of assets. As of June 30, 2023, excluding current portion of restricted cash, we had total cash and cash equivalents and short-term investments of $191.7 million, compared to $263.5 million as of December 31, 2022.

We expect cash provided by our operating activities to fluctuate depending on our operating results, which can be affected by the factors described above, as well as the other factors described in this MD&A and Part II, Item 1A. “Risk Factors” of this report.

Subject to the following paragraph, we believe our cash and cash equivalents and short-term investments and anticipated cash provided by our operating and current or future financing activities will satisfy our expected business requirements for at least the 12 months following the date of this report. Subsequent to that period, we may need to raise additional capital to fund any planned or unanticipated capital expenditures, investments, debt repayments, share repurchases or other expenses that we cannot fund through cash on-hand, cash provided by our operations or other sources. Moreover, we may use our cash resources faster than we predict due to unexpected expenditures, the direct and indirect impacts of the COVID-19 pandemic, or higher-than-expected expenses due to unfavorable macroeconomic events, including inflationary pressures or otherwise, in which case we may need to seek capital from alternative sources sooner than we anticipate. The timing and necessity of any future capital raise would depend on various factors, including our rate and volume of, and prices for, natural gas fuel sales and other volume-related activity, the direct and indirect impacts of the COVID-19 pandemic, new station construction, debt repayments (either before or at maturity) and any potential mergers, acquisitions, investments, divestitures or other strategic relationships we may pursue, as well as the other factors that affect our revenue and expense levels as described in this MD&A and elsewhere in this report.

If we deploy additional capital to develop ADG RNG production facilities and fueling stations to support contracted RNG fueling volume, we could be required to raise additional capital.

We may raise additional capital through one or more sources, including, among others, obtaining equity capital, including through offerings of our common stock or other securities, obtaining new or restructuring existing debt, selling assets, or any combination of these or other potential sources of capital. We may not be able to raise capital when needed, on terms that are favorable to us or our stockholders or at all. Any inability to raise necessary capital may impair our ability to develop and maintain fueling infrastructure, invest in strategic transactions or acquisitions or repay our outstanding indebtedness and may reduce our ability to support and build our business and generate sustained or increased revenue.

Off-Balance Sheet Arrangements

As of June 30, 2023, we had the following off-balance sheet arrangements that have had, or are reasonably likely to have, a material current or future effect on our financial condition, changes in financial condition, revenue or expenses, results of operations, liquidity, capital expenditures or capital resources:

●

Outstanding surety bonds for construction contracts and general corporate purposes totaling $50.4 million;

●

An outstanding loan commitment to an equity method investee;

●

Quarterly fixed-price natural gas purchase contracts with take-or-pay commitments; and

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●

One long-term natural gas sale contract with a fixed supply commitment.

We provide surety bonds primarily for construction contracts in the ordinary course of our business, as a form of guarantee. No liability has been recorded in connection with our surety bonds because, based on historical experience and available information, we do not believe it is probable that any amounts will be required to be paid under these arrangements for which we will not be reimbursed.

In November 2022, we entered into an agreement with one of our equity method investees pursuant to which we committed to make available up to $5.5 million in delayed draw loans to support the equity method investee’s working capital requirements.

As of June 30, 2023, we had quarterly fixed-price natural gas purchase contracts with take-or-pay commitments extending through June 2024.

In addition, as of June 30, 2023, we had a fixed supply arrangement with UPS for the supply and sale of 170.0 million GGEs of RNG through March 2026.

Item 3.—Quantitative and Qualitative Disclosures about Market Risk

In the ordinary course of our business, we are exposed to various market risks, including commodity price risks, risks related to foreign currency exchange rates, and risks related to fluctuations in interest rates.

Commodity Price Risk

We are subject to market risk with respect to our sales of natural gas, which have historically been subject to volatile market conditions. Our exposure to market risk is heightened when we have a fixed-price sales contract with a customer that is not covered by a futures contract, or when we are otherwise unable to pass through natural gas price increases to customers. Natural gas prices and availability are affected by many factors, including, among others, drilling activity, supply, weather conditions, the global trade environment, overall economic conditions and foreign and domestic government regulations.

Natural gas costs represented $182.4 million of our total cost of sales in 2022 and $117.2 million of our total cost of sales for the six months ended June 30, 2023.

In October 2018, in support of our Zero Now truck financing program, we entered into two commodity swap contracts with TotalEnergies Gas & Power North America, an affiliate of TotalEnergies and THUSA, for a total of five million diesel gallons annually from April 1, 2019 to June 30, 2024. These commodity swap contracts are intended to manage risks related to the diesel-to-natural gas price spread associated with the natural gas fuel supply commitments we make in our fueling agreements with fleet operators who participate in the Zero Now truck financing program.

We have prepared a sensitivity analysis to estimate our exposure to price risk with respect to our commodity swap contracts. If the diesel-to-natural gas price spread were to fluctuate by 10% as of June 30, 2023, then we would expect a corresponding fluctuation in the fair value of our commodity swap contracts of approximately $0.6 million.

Foreign Currency Exchange Rate Risk

For the three and six months ended June 30, 2023, our primary exposure to foreign currency exchange rates relates to our Canadian operations that had certain outstanding accounts receivable and accounts payable denominated in Canadian dollar, which were not hedged.

We performed a sensitivity analysis to estimate our exposure to market risk with respect to our monetary transactions denominated in a foreign currency. If the exchange rates on these assets and liabilities were to fluctuate by 10% from the rates as of June 30, 2023, we would expect a corresponding fluctuation in the value of the net assets to be immaterial.

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Interest Rate Risk

As of June 30, 2023, we had $150.0 million of debt that bears interest at a rate equal to either adjusted Term SOFR, the Federal Funds Effective Rate, or the Prime Rate plus a margin per annum. Thus, depending on our interest rate election during the period, our interest expense would fluctuate with a change in Term SOFR, the Federal Funds Effective Rate or the Prime Rate. If these rates were to increase or decrease by 1% for the year, then the impact on our annual interest expense would be approximately $1.5 million.

Certain LIBOR tenors were discontinued after 2021 with other LIBOR tenors discontinued after June 2023. We intend to monitor the developments with respect to the discontinuance of LIBOR and work with our lenders to minimize the effect of such a discontinuance on our financial condition and results of operations. To date, the effect of the discontinuance of LIBOR on us and on our debt instruments has not been material. However, if our lenders have increased costs due to changes in LIBOR, we may experience potential increases in interest rates on our variable rate debt, which could adversely affect our interest expense, results of operations and cash flows.

Item 4.—Controls and Procedures

Evaluation of Disclosure Controls and Procedures

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

Our management carried out an evaluation, with the participation of our Chief Executive Officer and Chief Financial Officer (our principal executive and principal financial officers, respectively), of the effectiveness of our disclosure controls and procedures as of June 30, 2023. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of June 30, 2023.

Changes in Internal Control over Financial Reporting

We regularly review and evaluate our internal control over financial reporting, and from time to time we may make changes to our processes and systems to improve controls or increase efficiencies. Such changes may include, among others, implementing new and more efficient systems, consolidating activities, and migrating processes.

There were no changes in our internal control over financial reporting that occurred during our most recently completed fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Inherent Limitations of Disclosure Controls and Procedures and Internal Control Over Financial Reporting

In designing our disclosure controls and procedures and internal control over financial reporting, management recognizes that any controls and procedures, no matter how well-designed and operated, can provide only reasonable assurance of achieving the desired control objectives. In addition, the design of our controls and procedures must reflect the fact that there are resource constraints, and management necessarily applies its judgment in evaluating the benefits of possible controls and procedures relative to their costs. Because of these inherent limitations, our disclosure and internal controls may not prevent or detect all instances of fraud, misstatements or other control issues. In addition, projections of any evaluation of the effectiveness of disclosure or internal controls to future periods are subject to risks, including, among others, that controls may become inadequate because of changes in conditions or that compliance with policies or procedures may deteriorate.

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PART II.—OTHER INFORMATION

Item 1. —Legal Proceedings

From time to time, we may become involved in various legal proceedings that arise in the ordinary course of our business, including lawsuits, claims, audits, government enforcement actions and related matters. It is not possible to predict when or if these proceedings may arise, nor is it possible to predict the outcome of any proceedings that do arise, including, among other things, the amount or timing of any liabilities we may incur, and any such proceedings could have a material effect on us regardless of outcome. In the opinion of management, however, we are not a party, and our properties are not subject, to any pending legal proceedings that are material to us.

Item 1A. —Risk Factors

An investment in our Company involves a high degree of risk of loss. You should carefully consider the risk factors discussed below and all of the other information included in this report before you make any investment decision regarding our securities. We believe the risks and uncertainties described below are the most significant we face, but additional risks and uncertainties not known to us or that we currently deem immaterial could also be or become significant. The occurrence of any of these risks could harm our business, financial condition, results of operations, prospects and reputation and could cause the trading price of our common stock to decline.

Risks Related to Our Business

Our success is dependent on the willingness of fleets and other consumers to adopt our vehicle fuels, which may not occur in a timely manner, at expected levels or at all.

Our success is highly dependent on the adoption by fleets and other consumers of our RNG and conventional natural gas vehicle fuels. The market for our vehicle fuels has experienced slow, volatile and unpredictable growth in many sectors. For example, adoption and deployment of our vehicle fuels in heavy-duty trucking has been slower and more limited than we anticipated. Also, other important fleet markets, including airports and public transit, had slower volume and customer growth in recent years that may continue. If the market for our vehicle fuels does not develop at improved rates or levels, or if a market develops but we are not able to capture a significant share of the market or the market subsequently declines, our business, prospects, financial condition, and operating results would be harmed.

Factors that may influence the adoption of our vehicle fuels, many of which are beyond our control, include, among others:

●

Lack of demand for trucks that use our vehicle fuels;

●

Adoption or expansion of government policies, programs, funding or incentives, or increased publicity or popular sentiment in favor of vehicles or fuels other than RNG and natural gas, including long-standing support for gasoline and diesel-powered vehicles, changes to emissions requirements applicable to vehicles and fleets powered by gasoline, diesel, RNG, natural gas, or other vehicle fuels and/or growing support for electric and hydrogen-powered vehicles;

●

Limitations on the capabilities of utilities to provide services to meet our requirements. For example, natural gas utilities may be unable to expand piping or provide services for new expansions, and electric utilities may lack the capacity to provide service for our projects;

●

Perceptions about the benefits of our vehicle fuels relative to gasoline, diesel and other alternative vehicle fuels, including with respect to factors such as supply, cost savings, environmental benefits and safety;

●

Increases, decreases or volatility in the supply, demand, use and prices of crude oil, gasoline, diesel, RNG, natural gas and other vehicle fuels, such as electricity, hydrogen, renewable diesel, biodiesel and ethanol;

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●

Inertia among fleets and fleet vehicle operators, who may be unable or unwilling to prioritize converting a fleet to our vehicle fuels over an operator’s other general business concerns, particularly if the operator is not sufficiently incentivized by emissions regulations or other requirements or lacks demand for the conversion from its customers, drivers, or other stakeholders;

●

Vehicle cost, fuel efficiency, availability, quality, safety, convenience (to fuel and service), design, performance and residual value, as well as operator perception with respect to these factors, generally and in our key customer markets and relative to comparable vehicles powered by other fuels;

●

The development, production, cost, availability, performance, sales and marketing and reputation of engines that are well-suited for the vehicles used in our key customer markets, including heavy-duty trucks and other fleets;

●

Increasing competition in the market for vehicle fuels generally, and the nature and effect of competitive developments in this market, including improvements in or perceived advantages of other vehicle fuels and engines powered by these fuels;

●

The availability and effect of environmental, tax or other government regulations, programs or incentives that promote our products or other alternatives as a vehicle fuel, including certain programs under which we generate credits by selling RNG as a vehicle fuel, as well as the market prices for such credits; and

●

Emissions and other environmental regulations and pressures on producing, transporting, and dispensing our fuels.

In June 2020, CARB adopted the Advanced Clean Trucks regulation, which requires manufacturers to sell a gradually increasing proportion of zero-emission electric trucks, vans and pickup trucks from 2024 onwards. By the year 2045, the Advanced Clean Trucks regulation seeks to have every new commercial vehicle sold in California be zero-emissions. Further, in September 2020, the Governor of the State of California issued an executive order (the “September 2020 Executive Order”) providing that it shall be the goal of California that (i) 100% of in-state sales of new passenger cars and trucks will be zero-emission by 2035, (ii) 100% of medium- and heavy-duty vehicles in California will be zero-emission by 2045 for all operations, where feasible, and by 2035 for drayage trucks, and (iii) the state will transition to 100% zero-emission off-road vehicles and equipment by 2035 where feasible. The September 2020 Executive Order also directed CARB to develop and propose regulations and strategies aimed at achieving the foregoing goals. Resulting regulations mandate increasing adoption of zero-emission vehicles. In April 2023, CARB adopted the Advanced Clean Fleets regulation, which requires all truck fleets be zero emission by 2042. The Advanced Clean Fleets regulation also seeks to end the sale of combustion trucks in California in 2036. Among other things, we believe the intent of the Advanced Clean Trucks regulation, the September 2020 Executive Order, and the Advanced Clean Fleets regulation is to limit and ultimately discontinue the production and use of internal combustion engines because such engines have “tailpipe” emissions. Implementation of such regulations and executive actions may slow, delay or prevent the adoption by fleets and other commercial consumers of our vehicle fuels, particularly in California. Moreover, other states have taken steps to enact similar regulations, which may slow, delay, change, or prevent the adoption of our vehicle fuels in those states as well. These actions could result in state funding and incentive programs being directed only to the adoption of electric vehicles. In December 2021, President Biden signed an executive order (the “2021 Executive Order”) that directs the federal government to achieve certain goals, including purchasing 100% zero-emission vehicles by 2035 for its fleet of over 600,000 cars and trucks.

Our RNG business may not be successful.

Our RNG business consists of procuring RNG from projects we plan to develop and own or from projects owned by third-party producers and reselling this RNG through our fueling infrastructure.

The success of our RNG business depends on our ability to secure, on acceptable terms, a sufficient supply of RNG; sell this RNG in adequate volumes and at prices that are attractive to customers and produce acceptable margins for

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us; and sell Environmental Credits we may generate under applicable federal or state programs from our sale of RNG as a vehicle fuel at favorable prices.

Our ability to maintain an adequate supply of RNG is subject to risks affecting RNG production. Projects that produce RNG often experience unpredictable production levels or other difficulties due to a variety of factors, including, among others, problems with equipment, severe weather, including as a result of climate change, droughts, financial condition of the applicable ADG and LFG source owner, health crises and pandemics, construction delays, technical difficulties, high operating costs, limited availability, unfavorable composition of collected feedstock gas, and plant shutdowns caused by upgrades, expansion or required maintenance. In addition, increasing demand for RNG will result in more robust competition for supplies of RNG, including from other vehicle fuel providers, gas utilities (which may have distinct advantages in accessing RNG supply including potential use of ratepayer funds to fund RNG purchases if approved by a utility’s regulatory commission) and other users and providers. If we or any of our RNG suppliers experience these or other difficulties in RNG production processes, or if competition for RNG development projects and supply increases, then our supply of RNG and our ability to resell it as a vehicle fuel could be jeopardized.

Our ability to generate revenue from our sale of RNG or our generation and sale of Environmental Credits depends on many factors, including the markets for RNG as a vehicle fuel and for Environmental Credits. The markets for Environmental Credits have been volatile and unpredictable in recent periods, and the prices for these credits are subject to fluctuations. For example, during 2022, market prices for RINs were as high as $3.56 and as low as $2.47. Additionally, the value of Environmental Credits, and consequently the revenue levels we may receive from our sale of these credits, may be adversely affected by changes to the federal and state programs under which these credits are generated and sold, prices for and use of oil, diesel or gasoline, the inclusion of additional qualifying fuels in the programs, increased production and use of other fuels in the programs, or other conditions. Our ability to generate revenue from sales of Environmental Credits depends on our strict compliance with these federal and state programs, which are complex and can involve a significant degree of judgment. If the agencies that administer and enforce these programs disagree with our judgments, otherwise determine we are not in compliance, conduct reviews of our activities or make changes to the programs, then our ability to generate or sell these credits could be restricted, permanently limited, or lost entirely, and we could also be subject to fines or other sanctions. Any of these outcomes could force us to purchase credits in the open market to cover any credits we have contracted to sell, retire credits we may have generated but not yet sold, reduce or eliminate a significant revenue stream, or incur substantial additional and unplanned expenses. Any permanent or temporary discontinuation or suspension of federal and state programs that provide credits, grants and incentives, such as the AFTC, would also adversely impact our revenue. Moreover, in the absence of programs that allow us to generate and sell Environmental Credits or other federal and state programs that support the RNG vehicle fuel market, or if our customers are not willing to pay a premium for RNG, we may be unable to operate our RNG business profitably or at all.

Our commercial success depends on our ability and the ability of our third-party supply sources to successfully develop and operate projects and produce expected volumes of RNG.

Our specific focus on RNG exposes us to risks related to the supply of and demand for RNG and Environmental Credits, the cost of capital expenditures, government regulation, and economic conditions, among other factors. As an RNG supplier we may also be negatively affected by lower RNG production resulting from lack of feedstock, mechanical breakdowns, faulty technology, competitive markets, or changes to the laws and regulations that mandate the use of renewable energy sources.

In addition, other factors related to the development and operation of renewable energy projects could adversely affect our business, including: (i) changes in pipeline gas quality standards or other regulatory changes that may limit our ability to transport RNG on pipelines for delivery to vehicles or increase the costs of processing RNG to allow for such deliveries; (ii) construction risks, including the risk of delay, that may arise because of inclement weather, natural disasters, accidents, labor disruptions, disputes, or increases in costs for or shortages of equipment and construction materials; (iii) operating risks; (iv) weather conditions; (v) financial condition of the applicable source owner; (vi) health of the applicable dairy herd; (vii) consolidation in the dairy industry; (viii) budget overruns; (ix) possible liabilities because of unforeseen environmental, construction, technological or other complications; (x) failures or delays in obtaining desired or necessary rights, including leases and feedstock agreements; and (xi) failures or delays in obtaining and keeping in good standing permits, authorizations and consents from local city, county, state and U.S. federal governments as well as local and U.S.

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federal governmental organizations. Any of these factors could prevent completion or operation of projects, or otherwise adversely affect our business, financial condition, and results of operations.

Acquisition, financing, construction, and development of projects by us or our partners that own projects may not commence on anticipated timelines or at all.

Our strategy is to continue to expand, including through the acquisition of additional projects and by signing additional supply agreements with third-party project owners. From time to time we and our partners enter into nonbinding letters of intent for projects. Until the negotiations are final, however, and the parties have executed definitive documentation, we or our partners may not be able to consummate any development or acquisition transactions, or any other similar arrangements, on the terms set forth in the applicable letter of intent or at all.

The acquisition, financing, construction and development of projects involves numerous risks, including: the ability to obtain financing for a project on acceptable terms or at all; difficulties in identifying, obtaining, and permitting suitable sites for new projects; failure to obtain all necessary rights to land access and use; inaccuracy of assumptions with respect to the cost and schedule for completing construction; inaccuracy of assumptions with respect to the biogas potential, including quality, volume, and asset life; delays in deliveries or increases in the price of equipment; permitting and other regulatory issues, license revocation and changes in legal requirements; increases in the cost of labor, labor disputes and work stoppages; potential business or financial stress of partners; failure to receive quality and timely performance of third-party or utility services; unforeseen engineering and environmental problems; cost overruns; accidents involving personal injury or the loss of life; and weather conditions, catastrophic events, including fires, explosions, earthquakes, droughts and acts of terrorism, and other force majeure events.

We are dependent on the production of vehicles and engines in our key customer and geographic markets by vehicle and engine manufacturers, over which we have no control.

Vehicle and engine manufacturers control the development, production, quality assurance, cost and sales and marketing of their products, which shapes the performance, availability and reputation of these products in the marketplace. We are dependent on these manufacturers to succeed in our target markets, and we have no influence or control over their activities. For example, Cummins is the only engine manufacturer for the RNG and natural gas heavy-duty truck market in the United States, and Cummins and other original equipment manufacturers currently produce a relatively small number of engines and vehicles that use our vehicle fuels. These manufacturers may decide not to expand or maintain, or may decide to discontinue or curtail, their engine or vehicle product lines for a variety of reasons, including as a result of the adoption of government policies or programs such as the Advanced Clean Trucks regulation, the September 2020 Executive Order and the Advanced Clean Fleets regulation. Further, the supply of engines or vehicle product lines by these manufacturers has been and continues to be disrupted/delayed due to the lingering impacts of global supply chain issues. The limited production of engines and vehicles that use our fuels increases their cost and limits availability, which restricts large-scale adoption, and may reduce resale value, which may contribute to operator reluctance to convert their fleets to vehicles that use our fuels. In addition, some operators have communicated to us that earlier models of heavy-duty truck engines using our fuels have a reputation for unsatisfactory performance, and that this reputation or their first-hand experiences of such performance may be a factor in operator decisions regarding whether to convert their fleets to vehicles that use our fuels.

To secure ADG RNG from new projects we develop, we typically face a long and variable development cycle that requires significant resource commitments and a long lead time before we realize revenue.

The development, design and construction process for ADG RNG projects generally lasts between 12 to 24 months on average. Prior to entering into a letter of intent with respect to an ADG RNG project, we typically conduct a preliminary assessment of whether the site is commercially viable based on our expected return on investment, investment payback period, and other operating metrics, as well as whether the necessary permits to develop a project on that site are available. After entering into a project letter of intent, we perform a more detailed review of the site’s facilities, including a life-cycle assessment, which serves as the basis for the final specifications of the project. Finally, we negotiate and execute contracts with the site owner and other parties. This extended development process requires the dedication of significant time and resources from our personnel, with no certainty of success or recovery of our expenses. Further, upon

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commencement of operations, it takes about 15-18 months for the project to ramp up to expected production level, receive necessary registrations and approvals from the EPA and CARB, and begin generating revenue. All these factors, and in particular, expenditures on development of projects that will not generate significant revenue in the near term, can contribute to fluctuations in our quarterly financial performance and increase the likelihood that our operating results in a particular period will fall below investor expectations.

Livestock waste and dairy farm projects are more dependent on LCFS credits and RINS, and therefore have different economic models and risk profiles than, landfill facilities, and we may not be able to achieve the operating results we expect from these projects.

Livestock waste and dairy farm projects produce less RNG and have higher capital and operating costs than landfill facilities. As a result, these projects are even more dependent on the LCFS credits and, to a lesser extent, RINs for commercial viability. If CARB reduces the CI score that it applies to waste conversion projects, such as dairy digesters, the number of LCFS credits for RNG generated at livestock waste and dairy farm projects will decline. Additionally, revenue from LCFS credits also depends on the price per LCFS credit, which is driven by various market forces, including the supply of and demand for LCFS credits, which in turn depends on the demand for traditional transportation fuel and the supply of renewable fuel from other renewable energy sources, and mandated CI targets, which determine the number of LCFS credits required to offset LCFS deficits. Fluctuations in the price of LCFS credits or the number of LCFS credits assigned will have a significantly greater effect on the success of livestock waste and dairy farm projects. RINs and LCFS Credit prices have fluctuated in recent years and will likely continue to be volatile. A significant decline in the value of LCFS credits could adversely affect our business, financial condition, and results of operations.

We have a history of losses and may incur additional losses in the future.

We incurred pre-tax losses in 2020, 2021, 2022, and in the six months ended June 30, 2023. During 2020, 2021, 2022, and the six months ended June 30, 2023, our results were positively affected by $19.8 million, $20.7 million, $21.8 million, and $9.6 million of AFTC revenue, respectively. We may incur losses in future periods, and we may never sustain profitability, either of which would adversely affect our business, prospects and financial condition and may cause the price of our common stock to fall. Furthermore, historical losses may not be indicative of future losses, and our future losses may be greater than our past losses. In addition, to try to achieve or sustain profitability, we may choose or be forced to take actions that result in material costs or material asset or goodwill impairments. For instance, we have recorded significant charges in connection with our former fueling compressor manufacturing business (which we combined with another company’s fueling compressor manufacturing business in the CEC Combination (as defined in Note 3 to the Condensed Consolidated Financial Statements)), our closure of certain fueling stations, our determination that certain assets were impaired because of the foregoing, and other actions. We review our assets for impairment whenever events or changes in circumstances indicate that the carrying value of an asset or asset group may not be recoverable, and we perform a goodwill impairment test on an annual basis and between annual tests in certain circumstances, in each case in accordance with applicable accounting guidance and as described in the financial statements and related notes included in this report. Changes to the use of our assets, divestitures, changes to the structure of our business, significant negative industry or economic trends, disruptions to our operations, inability to effectively integrate any acquired businesses, further market capitalization declines, or other similar actions or conditions could result in additional asset impairment or goodwill impairment charges or other adverse consequences, any of which could have material negative effects on our financial condition, our results of operations and the trading price of our common stock.

Our plans for hydrogen and electric vehicle stations will require significant cash investments and management resources and may not meet our expectations.

As operators deploy hydrogen powered vehicles, we plan to modify our fueling stations to reform our RNG, build additional hydrogen stations, and deliver clean hydrogen. Further, we have the capability to add electric charging at our sites, and we believe our RNG can be used to generate clean electricity to power vehicles.

Our plans will require significant cash investments and management resources and may not meet our expectations with respect to additional sales of our vehicle fuels. We have experience constructing hydrogen fueling stations, but such facilities cost significantly more than traditional RNG vehicle fueling stations. In addition, we have not yet added electric

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charging capability to any of our stations, and the cost of such capability may be significant. We will need to ensure compliance with all applicable regulatory requirements, including obtaining any required permits and land use rights, which could take considerable time and expense and is subject to the risk that government support in certain areas may be discontinued. If we are unable to modify our stations to provide hydrogen or add electric charging to our stations, or if we experience delays in doing so, our stations may be unable to meet our customer demand, which may negatively impact our business, prospects, financial condition, and operating results.

Various manufacturers have announced their plans to bring long-haul Class 8 commercial hydrogen- and battery-powered vehicles to the market over the coming years. We will, however, be dependent on these manufacturers to succeed in our target markets, and we will have no influence over their activities. See the risks discussed under “We are dependent on the production of vehicles and engines in our key customer and geographic markets by vehicle and engine manufacturers, over which we have no control,” above and elsewhere in these risk factors.

Increases, decreases and general volatility in oil, gasoline, diesel, natural gas and RNG prices could adversely affect our business.

The prices of RNG, natural gas, crude oil, gasoline and diesel can be volatile, and this volatility may continue to increase. Factors that may cause volatility in the prices of RNG, natural gas, crude oil, gasoline and diesel include, among others, changes in supply and availability of crude oil, RNG, and natural gas, government regulations, inventory levels, consumer demand, price and availability of alternatives, weather conditions, negative publicity about crude oil or natural gas drilling, production or transportation techniques and methods, worldwide economic, military, health and political conditions, transportation costs and the price of foreign imports. If the prices of crude oil, gasoline and diesel are low or decline, or if the price of RNG or natural gas increases without corresponding increases in the prices of crude oil, gasoline and diesel or Environmental Credits, we may not be able to offer our customers an attractive price for our vehicle fuels, market adoption of our vehicle fuels could be slowed or limited and/or we may be forced to reduce the prices at which we sell our vehicle fuels in order to try to attract new customers or prevent the loss of demand from existing customers. Natural gas and crude oil prices are expected to remain volatile for the near future because of market uncertainties over supply and demand, including due to the state of the world economy, geopolitical conditions, military conflicts such as the war in Ukraine, energy infrastructure and other factors. Fluctuations in natural gas prices affect the cost to us of the natural gas commodity. High natural gas prices adversely affect our operating margins when we cannot pass the increased costs through to our customers. Conversely, lower natural gas prices reduce our revenue when the commodity cost is passed through to our customers.

Pricing conditions may also exacerbate the cost differential between vehicles that use our fuels and gasoline or diesel-powered vehicles, which may lead operators to delay or refrain from purchasing or converting to our vehicle fuels. Generally, vehicles that use our fuels cost more initially than gasoline or diesel-powered vehicles because the components needed for a vehicle to use our fuels add to the vehicle’s base cost. Operators then seek to recover the additional base cost over time through a lower cost to use our fuels. Operators may, however, perceive an inability to timely recover these additional initial costs if our vehicle fuels are not available at prices sufficiently lower than gasoline and diesel. Such an outcome could decrease our potential customer base and harm our business prospects.

We face increasing competition from competitors, many of which have far greater resources, experience, customer bases and brand awareness than we have, and we may not be able to compete effectively with these businesses.

The market for vehicle fuels is highly competitive. The biggest competition for our products is gasoline and diesel because most vehicles in our key markets are powered by these fuels. We also compete with suppliers of other alternative vehicle fuels, including renewable diesel, biodiesel, and ethanol, as well as producers and fuelers of alternative vehicles, including hybrid, electric and hydrogen-powered vehicles. Additionally, our stations compete directly with other natural gas fueling stations and indirectly with electric vehicle charging stations and fueling stations for other vehicle fuels.

Many businesses are in the market for RNG and other alternatives for use as vehicle fuel, including alternative vehicle and alternative fuel companies, refuse collectors, industrial gas companies, private equity groups, commodity traders, truck stop and fuel station owners, fuel providers, gas marketers, utilities and their affiliates and other organizations. If the alternative vehicle fuel market grows, the number and type of participants in this market and their

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level of capital and other commitments to alternative vehicle fuel programs could increase. Many of our competitors have substantially greater experience, customer bases, brand awareness and financial, marketing and other resources than we have. As a result, these competitors may be able to respond more quickly to changes in customer preferences, legal requirements or other industry or regulatory trends; devote greater resources to the development, promotion and sale of their products; adopt more aggressive pricing policies; dedicate more effort to infrastructure and systems development in support of their business or product development activities; implement more robust or creative initiatives to advance consumer acceptance of their products; or exert more influence on the regulatory landscape that affects the vehicle fuels market.

We expect competition to increase in the vehicle fuels market generally. In addition, if the demand for alternative vehicle fuels, including RNG, increases, then we expect competition to also increase. Any such increased competition may reduce our customer base and revenue and may lead to increased pricing pressure, reduced operating margins and fewer expansion opportunities.

NG Advantage may not be successful.

NG Advantage provides “virtual pipelines” to transport CNG by truck from compression facilities to pipeline interconnects and to industrial and commercial customer users that do not have direct access to natural gas pipelines. NG Advantage faces unique risks, including among others: (i) it has a history of net losses and has incurred substantial indebtedness; (ii) NG Advantage will need to raise additional capital, which may not be available, may only be available on onerous terms, or may only be available from the Company; (iii) the labor market for truck drivers is very competitive, which increases NG Advantage’s difficulty in meeting its delivery obligations; (iv) NG Advantage often transports CNG in trailers over long distances and these trailers may be involved in accidents; and (v) NG Advantage’s CNG trailers may become subject to new or changed regulations that could adversely affect its business. If NG Advantage fails to manage any of these risks, our business, financial condition, liquidity, results of operations, prospects and reputation may be harmed. In addition, we have been a significant source of financing for NG Advantage. If NG Advantage is not able to obtain financing from external sources, we may need to provide additional debt or equity capital to allow NG Advantage to satisfy its commitments and maintain operations.

Our station construction activities subject us to business and operational risks.

As part of our business activities, we design and construct vehicle fueling stations that we either own and operate ourselves or sell to our customers. These activities require a significant amount of judgment in determining where to build and open fueling stations, including predictions about fuel demand that may not be accurate for any of the locations we target. As a result, we have built stations that we may not open for fueling operations, and we may open stations that fail to generate the volume or profitability levels we anticipate, either or both of which could occur due to a lack of sufficient customer demand at the station locations or for other reasons. For any stations that are completed but unopened, we would have substantial investments in assets that do not produce revenue, and for any stations that are open and underperforming, we may decide to close the stations. We determined to close a number of underperforming stations in the third and fourth quarters of 2017 and recorded impairment charges in connection with these closures and other related actions. As of June 30, 2023, we had 26 nearly completed stations with a carrying amount of $47.5 million that were not open for fueling operations. We do not know when or if these stations will open, and some of these stations are subject to agreements that may expire prior to us being able to open such stations. Closure of these and/or any other stations could result in substantial additional costs and non-cash asset impairments or other charges and could cause the price of our common stock to decline.

We also face many operational challenges in connection with our station design and construction activities. For example, we may not be able to identify suitable locations for the stations we or our customers seek to build. Additionally, even if preferred sites can be located, we may encounter land use or zoning difficulties, problems with utility services, challenges obtaining and retaining required permits and approvals or local resistance, including due to reduced operations of permitting agencies because of health crises, any of which could prevent us or our customers from building new stations on these sites or limit or restrict the use of new or existing stations. Any such difficulties, resistance or limitations or any failure to comply with local permit, land use or zoning requirements could restrict our activities or expose us to fines, reputational damage or other liabilities, which would harm our business and results of operations. In addition, we act as the general contractor and construction manager for new station construction and facility modification projects, and we

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typically rely on licensed subcontractors to perform the construction work. We may be liable for any damage we or our subcontractors cause or for injuries suffered by our employees or our subcontractors’ employees during the course of work on our projects. Additionally, shortages of skilled subcontractor labor could significantly delay a project or otherwise increase our costs. Further, our expected profit from a project is based in part on assumptions about the cost of the project, and cost overruns, delays or other execution issues may, in the case of projects we complete and sell to customers, result in our failure to achieve our expected margins or cover our costs, and in the case of projects we build and own, result in our failure to achieve an acceptable rate of return. If any of these events occur, our business, operating results and liquidity could be negatively affected.

We have significant contracts with government entities, which are subject to unique risks.

We have, and expect to continue to seek, long-term fueling station construction, maintenance and fuel sale contracts with various government bodies, which accounted for 22%, 31% and 27% of our revenue in 2020, 2021 and 2022, respectively. In addition to normal business risks, including the other risks discussed in these risk factors, our contracts with government entities are often subject to unique risks, some of which are beyond our control. For example, long-term government contracts and related orders are subject to cancellation if adequate appropriations for subsequent performance periods are not made. Further, the termination of funding for a government program supporting any of our government contracts or any other governmental action that results in reduced support for our government contracts could result in the loss of anticipated future revenue attributable to the contract. Moreover, government entities with which we contract are often able to modify, curtail or terminate contracts with us at their convenience and without prior notice, and would only be required to pay for work completed and commitments made at or prior to the time of termination.

In addition, government contracts are frequently awarded only after competitive bidding processes, which are often protracted. In many cases, unsuccessful bidders for government contracts are provided the opportunity to formally protest the contract awards through various agencies or other administrative and judicial channels. The protest process may substantially delay a successful bidder’s contract performance, result in cancellation of the contract award entirely and distract management. As a result, we may not be awarded contracts for which we bid, and substantial delays or cancellation of contracts may follow any successful bids as a result of any protests by other bidders. The occurrence of any of these risks would have a material adverse effect on our results of operations and financial condition.

We may from time to time pursue acquisitions, divestitures, investments or other strategic relationships or transactions, which could fail to meet expectations or otherwise harm our business.

We may acquire or invest in other companies or businesses or pursue other strategic transactions or relationships, such as joint ventures, collaborations, divestitures, or other similar arrangements. For example, in 2021 we created joint ventures with each of TotalEnergies and bp to develop and own dairy RNG production projects. These strategic transactions and relationships and any others we may pursue in the future involve numerous risks, any of which could harm our business, performance and liquidity, including, among others, the following: (i) difficulties integrating the operations, personnel, contracts, service providers and technologies of an acquired company or partner; (ii) diversion of financial and management resources from existing operations or alternative acquisition, investment, strategic or other opportunities; (iii) failure to realize the anticipated synergies or other benefits of a transaction or relationship; (iv) risks of entering new customer or geographic markets in which we may have limited or no experience; (v) potential loss of an acquired company’s or partner’s key employees, customers or vendors in the event of an acquisition or investment, or potential loss of our assets (and their associated revenue streams), employees or customers in the event of a divestiture or other strategic transaction; and (vi) incurrence of substantial costs or debt or equity dilution to fund an acquisition, investment or other transaction or relationship, as well as possible write-offs or impairment charges relating to any businesses we partner with, invest in or acquire.

Our partners may choose to invest in renewable or low carbon vehicle fuels other than RNG.

Our partners, including TotalEnergies, bp and Chevron, may reallocate their resources from RNG to other renewable or low carbon vehicle fuels. Any such action would have a material adverse effect on our plans, results of operations and financial condition.

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Our results of operations fluctuate significantly and are difficult to predict.

Our results of operations have historically experienced, and may continue to experience, significant fluctuations as a result of a variety of factors, including, among others, the amount and timing of our vehicle fuel sales, Environmental Credit sales and recognition of government credits, station construction sales, grants and incentives, such as AFTC (for example, we recorded all of the AFTC revenue associated with our vehicle fuel sales made in 2017 during the first quarter of 2018, and we recorded all of the AFTC revenue associated with our vehicles fuel sales made in 2018 and 2019 in the fourth quarter of 2019); fluctuations in commodity, station construction and labor costs; fluctuations in expenditures and resource commitments due to new ADG RNG project developments; variations in the fair value of certain of our derivative instruments that are recorded in revenue; sales of compressors and other equipment used in RNG production and at fueling stations; the amount and timing of our billing, collections and liability payments; and the other factors described in these risk factors.

Our performance in certain periods has also been affected by transactions or events that have resulted in significant cash or non-cash gains or losses. These or other similar gains or losses may not recur, in the same amounts or at all in future periods.

These significant fluctuations in our operating results may render period-to-period comparisons less meaningful, especially given uncertainties related to the impacts of the COVID-19 pandemic, and investors in our securities should not rely on the results of one period as an indicator of performance in any other period. Additionally, these fluctuations in our operating results could cause our performance in any period to fall below the financial guidance we may have provided to the public or the estimates and projections of the investment community, which could negatively affect the price of our common stock.

Our warranty reserves may not adequately cover our warranty obligations, which could result in unexpected costs.

We provide product warranties with varying terms and durations for the stations we build and sell, and we establish reserves for the estimated liability associated with these warranties. Our warranty reserves are based on historical trends and any specifically identified warranty issues known to us, and the amounts estimated for these reserves could differ materially from the warranty costs we may actually incur. We would be adversely affected by an increase in the rate or volume of warranty claims or the amounts involved in warranty claims, any of which could increase our costs beyond our established reserves and cause our cash position and financial condition to suffer.

The COVID-19 pandemic and measures intended to reduce its spread have adversely affected, and may continue to adversely affect, our business, results of operations and financial condition.

We may be subject to various risks and uncertainties because of the COVID-19 pandemic or other pandemics, epidemics, or infectious disease outbreaks, including a delay in the adoption of our RNG and natural gas vehicle fuels by heavy-duty trucks and/or a delay in increasing the use of our vehicle fuels; a decrease in the volume of truck and fleet operations, including shuttle buses at airports, and lower-than-normal levels of public transportation generally, which have resulted and may in the future result in decreased demand for our vehicle fuels; and the effect of business disruptions on the production of vehicles and engines that use our fuels, which has resulted in, and may in the future result in, plant closures, decreased manufacturing capacity, and delays in deliveries.

Risks Related to Our Indebtedness and Other Capital Resources.

We may need to raise additional capital to continue to fund our business, which could have negative effects and may not be available when needed, on acceptable terms or at all.

We require capital to pay for capital expenditures, operating expenses, any mergers, acquisitions or strategic investments, capital calls related to our joint ventures, transactions or relationships we may pursue, and to make principal and interest payments on our indebtedness. If we cannot fund any of these activities with capital on-hand or cash provided by our operations, we may seek to obtain additional capital from other sources, such as by selling assets or pursuing debt or equity financing.

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Asset sales and equity or debt financing may not be available when needed, on terms favorable to us or at all. Any sale of our assets to generate cash proceeds may limit our operational capacity and could limit or eliminate any revenue streams or business plans that are dependent on the sold assets. Any issuances of our common stock or securities convertible into our common stock to raise capital would dilute the ownership interest of our existing stockholders. Any debt financing we may pursue could require us to make significant interest or other payments and to pledge some or all of our assets as security. In addition, higher levels of indebtedness could increase our risk of non-repayment, adversely affect our creditworthiness, and amplify the other risks associated with our existing debt, which are discussed elsewhere in these risk factors. Further, we may incur substantial costs in pursuing any capital-raising transactions, including investment banking, legal and accounting fees. On the other hand, if we are unable to obtain capital in amounts sufficient to fund our obligations, expenses, and strategic initiatives, we could be forced to suspend, delay or curtail our business plans or operating activities or could default on our contractual commitments. Any such outcome could negatively affect our business, performance, liquidity, and prospects.

Our indebtedness could adversely affect our financial condition or operating flexibility and prevent us from fulfilling our obligations under our credit agreement and other indebtedness we may incur, and we may not generate sufficient cash flow from our business to pay our debt.

On December 22, 2022, we and our wholly-owned direct subsidiary Clean Energy entered into a senior secured first lien term loan agreement (the “Credit Agreement”) with the lenders from time to time party thereto (“Lenders”) and Riverstone Credit Management, LLC, as the administrative agent for the Lenders and collateral agent for the secured parties, pursuant to which the Lenders funded a $150,000,000 senior secured term loan. As of June 30, 2023, we had total consolidated indebtedness of $147.9 million, net of debt discount, and we may incur additional debt in the future. Our outstanding and any future indebtedness could make us more vulnerable to adverse changes in general U.S. and worldwide economic, regulatory, and competitive conditions, limit our flexibility to plan for or react to changes in our business or industry, place us at a disadvantage compared to our competitors that have less debt, or limit our ability to borrow or otherwise raise additional capital as needed.

Our payments of amounts owed under our various debt instruments will reduce our cash resources available for other purposes, including pursuing strategic initiatives, transactions or other opportunities, satisfying our other commitments, and generally supporting our operations. Moreover, our ability to make these payments depends on our future performance, which is subject to economic, financial, competitive and other factors, including those described in these risk factors, and many of which are beyond our control. Our business may not generate sufficient cash from operations to service our debt.

If we cannot meet our debt obligations from our operating cash flows, we may pursue one or more alternative measures. Any repayment of our debt with equity, however, would dilute the ownership interests of our existing stockholders. We are permitted under the Credit Agreement to incur additional debt under certain conditions. If new debt were to be incurred in the future, the related risks that we now face could intensify. The Credit Agreement requires us and our subsidiaries, on a consolidated basis, to comply with a maximum total leverage ratio, a minimum interest coverage ratio, and a minimum liquidity test. In addition, the Credit Agreement contains certain covenants that limit or restrict our and our subsidiaries’ ability to incur liens, incur indebtedness, dispose of assets, make investments, make certain restricted payments, merge or consolidate, amend our charter documents and certain other agreements, and enter into speculative hedging arrangements.

In the event of any default on our debt obligations, the holders of the indebtedness could, among other things, declare all amounts owed immediately due and payable and foreclose on our assets that serve as collateral. Any such declaration could deplete all or a large portion of our available cash flow, and thereby reduce the amount of cash available to pursue our business plans or force us into bankruptcy or liquidation.

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Risks Related to Environmental Health and Safety and Governmental and Environmental Regulations

Our business is influenced by environmental, tax and other government regulations, programs and incentives that promote our vehicle fuels, and their modification or repeal could negatively affect our business.

Our business is influenced by federal, state, and local tax credits, rebates, grants and other government programs and incentives that promote the use of our vehicle fuels. These include various government programs that make grant funds available from the purchase of vehicles and construction of fueling stations, as well as the AFTC under which we generate revenue for our vehicle fuel sales. Additionally, our business is influenced by laws, rules and regulations that require reductions in carbon emissions and/or the use of renewable fuels, such as the programs under which we generate Environmental Credits.

These programs and regulations, which have the effect of encouraging the use of RNG as a vehicle fuel, could expire or be repealed or amended for a variety of reasons. For example, parties with an interest in gasoline and diesel, electric or other alternative vehicles or vehicle fuels, including lawmakers, regulators, policymakers, environmental or advocacy organizations, producers of alternative vehicles or vehicle fuels, or other powerful groups, may invest significant time and money in efforts to delay, repeal or otherwise negatively influence regulations and programs that promote RNG. Many of these parties have substantially greater resources and influence than we have. Further, changes in federal, state or local political, social or economic conditions, including a lack of legislative focus on these programs and regulations, could result in their modification, delayed adoption or repeal. Any failure to adopt, delay in implementing, expiration, repeal or modification of these programs and regulations, or the adoption of any programs or regulations that encourage the use of other alternative fuels or alternative vehicles over RNG (such as the September 2020 Executive Order or the 2021 Executive Order), would reduce the market for RNG as a vehicle fuel and harm our operating results, liquidity, and financial condition.

For instance, California lawmakers and regulators have implemented various measures designed to increase the use of electric, hydrogen and other zero-emission vehicles, including establishing firm goals for the number of these vehicles operating on state roads by specified dates and enacting various laws and other programs in support of these goals. Although the influence and applicability of these or similar measures on our business remains uncertain, a focus on “zero tailpipe emission” vehicles over vehicles with an overall net carbon negative emissions profile, but with some tailpipe emissions operating on RNG, would adversely affect the market for our fuels.

To benefit from Environmental Credits, RNG projects are required to be registered and are subject to audit.

RNG projects are required to register with the EPA and relevant state regulatory agencies. Further, we qualify our RINs through a voluntary Quality Assurance Plan, which typically takes from three to five months from first injection of RNG into the commercial pipeline system. We also must certify RNG pathways with CARB, which typically takes from 15-18 months from first injection of RNG into the commercial pipeline system. Delays in obtaining registration, RIN qualification, and any LCFS credit qualification of a new project could delay future revenues from a project and could adversely affect our cash flow. Further, we may make large investments in projects prior to receiving the regulatory approval and RIN qualification. By registering RNG projects with the EPA’s voluntary Quality Assurance Plan and by establishing RNG pathways under CARB’s LCFS program, we are subject to third-party audits and on-site visits of projects to validate generated RINs and overall compliance with the federal renewable fuel standard and the LCFS. We are also subject to a separate third party’s annual attestation review. The Quality Assurance Plan provides a process for RIN owners to follow, for an affirmative defense to civil liability, if used or transferred Quality Assurance Plan verified RINs were invalidly generated. A project’s failure to comply could result in remedial action, including penalties, fines, retirement of RINs, or termination of the project’s registration, any of which could adversely affect our business, financial condition and results of operations.

Our business could be negatively affected by federal or state laws, orders or regulations mandating new or additional limits on GHG emissions, “tailpipe” emissions or internal combustion engines.

Federal or state laws, orders or regulations have been adopted, such as California’s AB 32 cap and trade law and the 2021 Executive Order, and may in the future be adopted that impose limits on GHG emissions or otherwise require the

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adoption of zero-emission electric vehicles. The effects of GHG emission limits on our business are subject to significant uncertainties based on, among other things, the timing of any requirements, the required levels of emission reductions, the nature of any market-based or tax-based mechanisms adopted to facilitate reductions, the relative availability of GHG emission reduction offsets, the development of cost-effective, commercial-scale carbon capture and storage technology and supporting regulations and liability mitigation measures, the range of available compliance alternatives, and our ability to demonstrate that our vehicle fuels qualify as a compliance alternative under any statutory or regulatory programs to limit GHG emissions. If our vehicle fuels are not able to meet GHG emission limits or perform as well as other alternative fuels and vehicles, our solutions could be less competitive. Furthermore, additional federal or state taxes could be implemented on “tailpipe” emissions, which would have a negative impact on the cost of our vehicle fuels, as compared to vehicle fuels that do not generate tailpipe emissions. See also the discussion above regarding the Advanced Clean Trucks regulation, the September 2020 Executive Order, the Advanced Clean Fleets regulation and the 2021 Executive Order under “Our success is dependent on the willingness of fleets and other consumers to adopt our vehicle fuels, which may not occur in a timely manner, at expected levels or at all.”

Our business is subject to a variety of government regulations, which may restrict our operations and result in costs and penalties or otherwise adversely affect our business and ability to compete.

We are subject to a variety of federal, state and local laws and regulations relating to the environment, health and safety, labor and employment, building codes and construction, zoning and land use, the government procurement process, any political activities or lobbying in which we may engage, public reporting and taxation, among others. It is difficult and costly to manage the requirements of every authority having jurisdiction over our various activities and to comply with their varying standards. Many of these laws and regulations are complex, change frequently, may be unclear and difficult to interpret and have become more stringent over time. Any changes to existing regulations, adoption of new regulations, or judicial rulings regarding such regulations, may result in significant additional expense to us or our customers. For example, the Advanced Clean Trucks regulation, the September 2020 Executive Order, the Advanced Clean Fleets regulation, and the 2021 Executive Order may restrict or adversely affect our business.

Further, from time to time, as part of the regular evaluation of our operations, including newly acquired or developing operations, we may be subject to compliance audits by regulatory authorities, which may distract management from our revenue-generating activities and involve significant costs and use of other resources. Also, we often need to obtain facility permits or licenses to address, among other things, storm water or wastewater discharges, waste handling and air emissions in connection with our operations, which may subject us to onerous or costly permitting conditions or delays if permits cannot be timely obtained. Our failure to comply with any applicable laws and regulations could result in a variety of administrative, civil and criminal enforcement measures, including, among others, assessment of monetary penalties, imposition of corrective requirements or prohibition from providing services to government entities. If any of these enforcement measures were imposed on us, our business, financial condition, and performance could be negatively affected.

We are subject to various environmental laws and regulations that could impose substantial costs upon us.

Our operations are and will be subject to federal, state and local environmental laws and regulations, including laws relating to the use, handling, storage, disposal of and human exposure to hazardous materials. Moreover, we expect that we will be affected by future amendments to such laws or other new environmental and health and safety laws and regulations which may require us to change our operations, potentially resulting in a material adverse effect on our business, prospects, financial condition, and operating results. These laws can give rise to liability for administrative oversight costs, cleanup costs, property damage, bodily injury, fines, and penalties. Capital and operating expenses needed to comply with environmental laws and regulations can be significant, and violations may result in substantial fines and penalties, third-party damages, suspension of production or a cessation of our operations.

Contamination at properties we own or operate, will own or operate, or formerly owned or operated or to which hazardous substances were sent by us, may result in liability for us under environmental laws and regulations, including, but not limited to, the Comprehensive Environmental Response, Compensation and Liability Act, which can impose liability for the full amount of remediation-related costs without regard to fault, for the investigation and cleanup of contaminated soil and ground water, for impacts to human health and for damages to natural resources. The costs of

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complying with environmental laws and regulations and any claims concerning noncompliance, or liability with respect to contamination in the future, could have a material adverse effect on our financial condition or operating results. We may face unexpected delays in obtaining the required permits and approvals in connection with our planned RNG production facilities that could require significant time and financial resources and delay our ability to operate these facilities, which would adversely impact our business, prospects, financial condition and operating results.

Our operations entail inherent safety and environmental risks, which may result in substantial liability to us.

Our operations entail inherent safety risks, including risks associated with equipment defects, malfunctions, failures, and misuses. For example, operation of LNG pumps requires special training because of the extremely low temperatures of LNG. Also, LNG tanker trailers and CNG fuel tanks and trailers could rupture if involved in accidents or improper maintenance or installation. Further, improper refueling of vehicles that use our fuels or operation of vehicle fueling stations could result in sudden releases of pressure that could cause explosions. In addition, our operations may result in the venting of methane, which is flammable and is a potent GHG. These safety and environmental risks could result in uncontrollable flows of our fuels, fires, explosions, death, or serious injury, any of which may expose us to liability for personal injury, wrongful death, property damage, pollution and other environmental damage. We may incur substantial liability and costs if any such damages are not covered by insurance or are more than policy limits, or if environmental damage causes us to violate applicable GHG emissions or other environmental laws. Additionally, the occurrence of any of these events with respect to our fueling stations or our other operations could materially harm our business and reputation. Moreover, the occurrence of any of these events to any other organization in our vehicle fuel business could harm our industry generally by negatively affecting perceptions about, and adoption levels of, our vehicle fuels.

Risks Related to Our Common Stock

A significant portion of our outstanding common stock is owned or otherwise subject to acquisition by two equityholders, each of which may have interests that differ from the Company’s other stockholders and which now or in the future may be able to influence the Company’s corporate decisions, including a change of control.

After giving effect to the issuance of the Amazon Warrant, Total Marketing Services, SAS (“TMS”), a wholly owned subsidiary of TotalEnergies, owns 42,581,801 shares of our common stock, or 19.7% of our outstanding shares of common stock as of June 30, 2023 (excluding 6,666,761 shares of our common stock that are the subject of a voting agreement, dated May 9, 2018, among TMS, the Company and all of the Company’s directors and officers then in office); the Amazon Warrant is immediately exercisable by Amazon Holdings for shares of our common stock representing 4.999% of our outstanding common stock. Subject to vesting of the Amazon Warrant, the Amazon Warrant will be exercisable for up to 19.999% of our outstanding common stock on a fully diluted basis (determined at the time of issuance of the Amazon Warrant), subject to certain anti-dilution provisions, and Amazon Holding’s beneficial ownership will initially be contractually limited to the beneficial ownership limitation unless Amazon Holdings gives the Company sixty one (61) days’ notice that it is waiving such limitation. In addition, TotalEnergies was granted certain special rights that our other stockholders do not have in connection with its acquisition of this ownership position, including the right to designate two individuals to serve as directors of our Company and a third individual to serve as an observer on certain of our board committees.

TotalEnergies or other large stockholders may be able to influence or control matters requiring approval by our stockholders, including the election of directors, mergers and acquisitions, or other extraordinary transactions. Amazon, through ownership by Amazon Holdings, could become a large stockholder if the Amazon Warrant were to vest further through additional fuel purchases from the Company pursuant to the Fuel Agreement, and Amazon Holdings were to exercise the Amazon Warrant to purchase vested Warrant Shares or Additional Warrant Shares and waive the Beneficial Ownership Limitation. Large stockholders may have interests that differ from other stockholders and may vote or otherwise act in ways with which the Company or other stockholders disagree or that may be adverse to your interests. A concentration of stock ownership may also have the effect of delaying, preventing or deterring a change of control of our Company, which could deprive our stockholders of an opportunity to receive a premium for their shares of our common stock as part of a sale of our Company and could affect the market price of our common stock. Conversely, such a concentration of stock ownership may facilitate a change of control under terms other stockholders may not find favorable or at a time when other stockholders may prefer not to sell.

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Sales of our common stock, or the perception that such sales may occur, could cause the market price of our stock to drop significantly, regardless of the state of our business.

All outstanding shares of our common stock are eligible for sale in the public market, subject in certain cases to the requirements of Rule 144 under the Securities Act. Also, shares of our common stock that may be issued upon the exercise, vesting or conversion of our outstanding stock options and restricted stock units may be eligible for sale in the public market, to the extent permitted by Rule 144 and the provisions of the applicable stock option and restricted stock unit agreements or if such shares have been registered under the Securities Act.

Sales of large amounts of our common stock by large stockholders, or the perception that such sales may occur, could cause the market price of our common stock to decline, regardless of the state of the Company’s business. Our common stock held by TMS and our common stock underlying the Amazon Warrant may be sold in the public market under Rule 144 or in registered sales or offerings pursuant to registration rights held by each stockholder. For instance, we filed a registration statement with the SEC to cover the resale of the shares of our common stock issued and sold to TMS, which registration statement was declared effective in August 2018. If these shares are sold, or if it is perceived that they may be sold, in the public market, the trading price of our common stock could decline. For instance, in the year ended December 31, 2021, TMS sold 8,274,495 shares of our common stock, which we believe caused downward pressure on the trading price of our common stock.

General Risk Factors

We rely on information technology in our operations, and any material failure, inadequacy, interruption, or security failure of that technology could harm our business.

Increased global IT security threats and more sophisticated and targeted computer crime pose a risk to the security of our systems and networks and the confidentiality, availability and integrity of our data. There have been several recent, highly publicized cases in which organizations of various types and sizes have reported the unauthorized disclosure of customer or other confidential information, as well as cyber incidents involving the dissemination, theft and destruction of corporate information, intellectual property, cash or other valuable assets. There have also been several highly publicized cases in which hackers have requested “ransom” payments in exchange for not disclosing customer or other confidential information or for not disabling the target company’s computer or other systems. Implementing security measures designed to prevent, detect, mitigate or correct these or other IT security threats involves significant costs. Although we have taken steps to protect the security of our information systems and the data maintained in those systems, we have, from time to time, experienced cyberattacks or other cyber incidents that have threatened our data and systems, including malware and computer virus attacks and it is possible that future cyber incidents we may experience may materially and adversely affect our business. We cannot provide assurance that our safety and security measures will prevent our information systems from improper functioning or damage, or the improper access or disclosure of personally identifiable information such as in the event of cyber incidents. Any IT security threats that are successful against our security measures could, depending on their nature and scope, lead to the compromise of confidential information, improper use of our systems and networks, manipulation and destruction of data, operational disruptions, and substantial financial outlays. Further, a cyber incident could occur and persist for an extended period of time without detection, and an investigation of any successful cyber incident would likely require significant time, costs and other resources to complete. We may be required to expend significant financial resources to protect against or to remediate such cyber incidents. In addition, our technology infrastructure and information systems are vulnerable to damage or interruption from natural disasters, power loss and telecommunications failures. Any failure to maintain proper function, security and availability of our information systems and the data maintained in those systems could interrupt our operations, damage our reputation, subject us to liability claims or regulatory penalties, harm our business relationships or increase our security and insurance costs, which could have a material adverse effect on our business, financial condition and results of operations.

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The price of our common stock may continue to fluctuate significantly, and you could lose all or part of your investment.

The market price of our common stock has experienced, and may continue to experience, significant volatility. Factors that may cause volatility in the price of our common stock, many of which are beyond our control, include, among others, the following: (i) the factors that may influence the adoption of our vehicle fuels, as discussed elsewhere in these risk factors; (ii) our ability to implement our business plans and initiatives and their anticipated, perceived or actual level of success; (iii) failure to meet or exceed any financial guidance we have provided to the public or the estimates and projections of the investment community; (iv) the market’s perception of the success and importance of any of our acquisitions, divestitures, investments or other strategic relationships or transactions; (v) the amount of and timing of sales of, and prices for, Environmental Credits; (vi) actions taken by state or federal governments to mandate or otherwise promote or incentivize alternative vehicles or vehicle fuels over, or to the exclusion of, RNG; (vii) technical factors in the public trading market for our common stock that may produce price movements that may or may not comport with macro, industry or company-specific fundamentals, including, without limitation, the sentiment of retail investors (including as may be expressed on financial trading and other social media sites), the amount and status of short interest in our common stock, access to margin debt, and trading in options and other derivatives on our common stock; (viii) changes in political, regulatory, health, economic and market conditions; and (ix) a change in the trading volume of our common stock.

In addition, the securities markets have from time-to-time experienced significant price and volume fluctuations that are unrelated to the operating performance of particular companies, but which have affected the market prices of these companies’ securities. These market fluctuations may also materially and adversely affect the market price of our common stock.

Volatility or declines in the market price of our common stock could have other negative consequences, including, among others, further impairments to our assets, potential impairments to our goodwill and a reduced ability to use our common stock for capital-raising, acquisitions or other purposes. The occurrence of any of these risks could materially and adversely affect our financial condition, results of operations and liquidity and could cause further declines in the market price of our common stock.

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

None.

Item 3.—Defaults Upon Senior Securities

None.

Item 4.—Mine Safety Disclosures

None.

Item 5.—Other Information

Rule 10b5-1 Plan Elections. On August 12, 2022, Andrew J. Littlefair, Chief Executive Officer, adopted a Rule 10b5-1 trading plan for the purpose of establishing a sales plan of the Company’s common stock that is intended to comply with the requirements of Rule 10b5-1(c)(1) under the Securities Exchange Act of 1934, as amended. Mr. Littlefair’s Rule 10b5-1 trading plan is in effect from November 13, 2022 to the earlier of (1) November 1, 2023 and (2) the date on which an aggregate of 500,000 shares of the Company’s common stock have been sold pursuant to the Rule 10b5-1 trading plan.

Item 6.—Exhibits

The information required by this Item 6 is set forth on the Exhibit Index that immediately precedes the signature page to this report and is incorporated herein by reference.

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EXHIBIT INDEX

Exhibit Number		Description
31.1*		Certification of Andrew J. Littlefair, President and Chief Executive Officer, pursuant to Rule 13a-14(a) or 15d-14(a) of the Exchange Act, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*		Certification of Robert M. Vreeland, Chief Financial Officer, pursuant to Rule 13a-14(a) or 15d-14(a) of the Exchange Act, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**		Certification of Andrew J. Littlefair, President and Chief Executive Officer, and Robert M. Vreeland, Chief Financial Officer, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101*		The following materials from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2023, formatted in iXBRL (Inline eXtensible Business Reporting Language):
		(i) Condensed Consolidated Balance Sheets as of December 31, 2022 and June 30, 2023;
		(ii) Condensed Consolidated Statements of Operations for the Three and Six Months Ended June 30, 2022 and 2023;
		(iii) Condensed Consolidated Statements of Comprehensive Loss for the Three and Six Months Ended June 30, 2022 and 2023;
		(iv) Condensed Consolidated Statements of Stockholders’ Equity for the Three and Six Months Ended June 30, 2022 and 2023;
		(v) Condensed Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2022 and 2023; and
		(vi) Notes to Condensed Consolidated Financial Statements.
104*		Cover Page Interactive Data File (formatted as iXBRL and contained in Exhibit 101).

* Filed herewith.

** Furnished herewith.

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SIGNATURE

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.

	CLEAN ENERGY FUELS CORP.

Date: August 9, 2023	By:	/s/ ROBERT M. VREELAND
		Robert M. Vreeland
		Chief Financial Officer (Principal financial officer and duly authorized to sign on behalf of the registrant)

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Clean Energy Fuels (CLNE) 10-Q2023 Q2 Quarterly report

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