Edgar Filing: Clean Energy Fuels Corp.

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2015

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)		(IRS 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)

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 x No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files). Yes x No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer x		Accelerated filer o

Non-accelerated filer o (Do not check if a smaller reporting company)		Smaller reporting company o

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

As of July 29, 2015, there were 90,560,410 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
Item 1.—Financial Statements (Unaudited)	3
Item 2.—Management’s Discussion and Analysis of Financial Condition and Results of Operations	21
Item 3.—Quantitative and Qualitative Disclosures about Market Risk	32
Item 4.—Controls and Procedures	32
PART II.—OTHER INFORMATION
Item 1.—Legal Proceedings	33
Item 1A.—Risk Factors	33
Item 2.—Unregistered Sales of Equity Securities and Use of Proceeds	45
Item 3.—Defaults upon Senior Securities	45
Item 4.—Mine Safety Disclosures	45
Item 5.—Other Information	45
Item 6.—Exhibits	46

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PART I.—FINANCIAL INFORMATION

Item 1.—Financial Statements (Unaudited).

Clean Energy Fuels Corp. and Subsidiaries

Condensed Consolidated Balance Sheets

December 31, 2014 and June 30, 2015

(Unaudited)

(In thousands, except share data)

	December 31, 2014			June 30, 2015
Assets
Current assets:
Cash and cash equivalents	$	92,381		$	53,296
Restricted cash	6,012			4,469
Short-term investments	122,546			128,596
Accounts receivable, net of allowance for doubtful accounts of $752 and $970 as of December 31, 2014 and June 30, 2015, respectively	81,970			78,537
Other receivables	56,223			18,656
Inventories	34,696			31,347
Prepaid expenses and other current assets	19,811			15,172
Total current assets	413,639			330,073
Land, property and equipment, net	514,269			520,424
Notes receivable and other long-term assets, net	71,904			69,362
Investments in other entities	6,510			5,961
Goodwill	98,726			95,831
Intangible assets, net	55,361			49,310
Total assets	$	1,160,409		$	1,070,961
Liabilities and Stockholders’ Equity
Current liabilities:
Current portion of long-term debt and capital lease obligations	$	4,846		$	5,977
Accounts payable	43,922			28,859
Accrued liabilities	56,760			51,327
Deferred revenue	14,683			5,566
Total current liabilities	120,211			91,729
Long-term debt and capital lease obligations, less current portion	500,824			504,769
Long-term debt, related party	65,000			65,000
Other long-term liabilities	9,339			7,971
Total liabilities	695,374			669,469
Commitments and contingencies
Stockholders’ equity:
Preferred stock, $0.0001 par value. Authorized 1,000,000 shares; issued and outstanding no shares	—			—
Common stock, $0.0001 par value. Authorized 224,000,000 shares; issued and outstanding 90,203,344 shares and 90,527,189 shares at December 31, 2014 and June 30, 2015, respectively	9			9
Additional paid-in capital	898,106			904,058
Accumulated deficit	(457,441		)	(518,533		)
Accumulated other comprehensive loss	(3,248		)	(10,878		)
Total Clean Energy Fuels Corp. stockholders’ equity	437,426			374,656
Noncontrolling interest in subsidiary	27,609			26,836
Total stockholders’ equity	465,035			401,492
Total liabilities and stockholders’ equity	$	1,160,409		$	1,070,961

See accompanying notes to condensed consolidated financial statements.

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Clean Energy Fuels Corp. and Subsidiaries

Condensed Consolidated Statements of Operations

For the Three Months and Six Months Ended June 30, 2014 and 2015

(Unaudited)

(In thousands, except share and per share data)

	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2015			2014			2015
Revenue:
Product revenues	$	86,473		$	75,744		$	172,262		$	145,041
Service revenues	11,660			11,124			21,146			27,675
Total revenues	98,133			86,868			193,408			172,716
Operating expenses:
Cost of sales (exclusive of depreciation and amortization shown separately below):
Product cost of sales	69,175			59,387			137,042			114,766
Service cost of sales	4,080			4,399			7,844			13,753
Derivative (gains) losses:
Series I warrant valuation	2,286			300			(2,169		)	(583		)
Selling, general and administrative	34,400			28,994			67,890			59,227
Depreciation and amortization	11,608			13,402			23,123			26,288
Total operating expenses	121,549			106,482			233,730			213,451
Operating loss	(23,416		)	(19,614		)	(40,322		)	(40,735		)
Interest expense, net	(10,130		)	(9,973		)	(19,640		)	(19,868		)
Other income (expense), net	1,121			317			(165		)	864
Loss from equity method investments	—			(345		)	—			(549		)
Loss before income taxes	(32,425		)	(29,615		)	(60,127		)	(60,288		)
Income tax expense	(147		)	(740		)	(1,109		)	(1,594		)
Net loss	(32,572		)	(30,355		)	(61,236		)	(61,882		)
Loss from noncontrolling interest	266			393			337			773
Net loss attributable to Clean Energy Fuels Corp.	$	(32,306	)	$	(29,962	)	$	(60,899	)	$	(61,109	)
Loss per share attributable to Clean Energy Fuels Corp.:
Basic	$	(0.34	)	$	(0.33	)	$	(0.64	)	$	(0.67	)
Diluted	$	(0.34	)	$	(0.33	)	$	(0.64	)	$	(0.67	)
Weighted-average common shares outstanding:
Basic	94,859,587			91,480,998			94,768,462			91,399,478
Diluted	94,859,587			91,480,998			94,768,462			91,399,478

See accompanying notes to condensed consolidated financial statements.

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Clean Energy Fuels Corp. and Subsidiaries

Condensed Consolidated Statements of Comprehensive Loss

For the Three Months and Six Months Ended June 30, 2014 and 2015

(Unaudited)

(In thousands)

	Clean Energy Fuels Corp.						Noncontrolling Interest						Total
	Three Months Ended June 30,						Three Months Ended June 30,						Three Months Ended June 30,
	2014			2015			2014			2015			2014			2015
Net loss	$	(32,306	)	(29,962		)	$	(266	)	$	(393	)	$	(32,572	)	$	(30,355	)

Other comprehensive income (loss), net of tax:
Foreign currency translation adjustments	(442		)	813			—			—			(442		)	813
Foreign currency adjustments on intra-entity long-term investments	3,495			535			—			—			3,495			535
Unrealized losses on available-for-sale securities	(81		)	(2		)	—			—			(81		)	(2		)
Total other comprehensive income, net of tax	2,972			1,346			—			—			2,972			1,346

Comprehensive loss	$	(29,334	)	$	(28,616	)	$	(266	)	$	(393	)	$	(29,600	)	$	(29,009	)

	Clean Energy Fuels Corp.						Noncontrolling Interest						Total
	Six Months Ended June 30,						Six Months Ended June 30,						Six Months Ended June 30,
	2014			2015			2014			2015			2014			2015
Net loss	$	(60,899	)	$	(61,109	)	$	(337	)	$	(773	)	$	(61,236	)	$	(61,882	)

Other comprehensive income (loss), net of tax:
Foreign currency translation adjustments	(246		)	(4,868		)	—			—			(246		)	(4,868		)
Foreign currency adjustments on intra-entity long-term investments	157			(2,776		)	—			—			157			(2,776		)
Unrealized (losses) gains on available-for-sale securities	(399		)	14			—			—			(399		)	14
Total other comprehensive loss, net of tax	(488		)	(7,630		)	—			—			(488		)	(7,630		)

Comprehensive loss	$	(61,387	)	$	(68,739	)	$	(337	)	$	(773	)	$	(61,724	)	$	(69,512	)

See accompanying notes to condensed consolidated financial statements.

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Clean Energy Fuels Corp.

Condensed Consolidated Statements of Cash Flows

For the Six Months Ended June 30, 2014 and 2015

(Unaudited)

(In thousands)

	Six Months Ended June 30,
	2014			2015
Cash flows from operating activities:
Net loss	$	(61,236	)	$	(61,882	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation and amortization	23,123			26,288
Provision for doubtful accounts, notes and inventory	112			1,440
Loss on disposal of assets	8			42
Derivative loss	(2,169		)	(583		)
Stock-based compensation expense	6,398			5,353
Amortization of debt issuance cost	1,527			1,534
Accretion of notes payable	138			36
Equity method investment loss	—			549
Loss on contingent consideration for acquisition	101			—
Changes in operating assets and liabilities, net of assets and liabilities acquired and disposed:
Accounts and other receivables	(7,209		)	40,636
Inventory	(5,382		)	3,293
Prepaid expenses and other assets	1,891			7,329
Accounts payable	(1,715		)	(11,570		)
Accrued expenses and other	1,126			(15,323		)
Net cash used in operating activities	(43,287		)	(2,858		)
Cash flows from investing activities:
Purchases of short-term investments	(70,868		)	(71,739		)
Maturities of short-term investments	55,144			64,861
Purchases and deposits on property and equipment	(61,840		)	(26,236		)
Loans made to customers	(2,295		)	(2,510		)
Payments on and proceeds from sales of loans receivable	2,240			892
Restricted cash	(3,846		)	1,543
Net cash used in investing activities	(81,465		)	(33,189		)
Cash flows from financing activities:
Proceeds from issuance of common stock and exercise of stock options	684			599
Proceeds from debt instruments	12,720			6
Proceeds from revolving line of credit	23,621			24
Repayment of borrowing under revolving line of credit	(17,645		)	(26		)
Repayment of capital lease obligations and debt instruments	(9,338		)	(2,509		)
Payments for debt issuance costs	(914		)	—
Net cash provided (used) by financing activities	9,128			(1,906		)
Effect of exchange rates on cash and cash equivalents	291			(1,132		)
Net decrease in cash	(115,333		)	(39,085		)
Cash, beginning of period	240,033			92,381
Cash, end of period	$	124,700		$	53,296
Supplemental disclosure of cash flow information:
Income taxes paid	$	690		$	497
Interest paid, net of approximately $1,992 and $534 capitalized, respectively	18,668			18,184

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)

(In thousands, except share and per share data)

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 otherwise) is engaged in the business of selling natural gas fueling solutions to its customers, primarily in the United States and Canada.

The Company designs, builds, operates and maintains fueling stations and supplies customers with compressed natural gas (“CNG”) fuel for light, medium and heavy-duty vehicles and liquefied natural gas (“LNG”) fuel for medium and heavy-duty vehicles. The Company also manufactures, sells and services non-lubricated natural gas fueling compressors and other equipment used in CNG stations and LNG stations, provides operation and maintenance (“O&M”) services to customers, offers assessment, design and modification solutions to provide operators with code-compliant service and maintenance facilities for natural gas vehicle fleets, transports and sells CNG to large industrial and institutional energy users who do not have direct access to natural gas pipelines, processes and sells renewable natural gas (“RNG”), which can be used as vehicle fuel or sold for renewable power generation, sells tradable credits generated by selling natural gas and RNG as a vehicle fuel, including credits generated under the California Low Carbon Fuel Standard (“LCFS Credits”) and Renewable Identification Numbers (“RIN Credits” or “RINs”) generated under the federal Renewable Fuel Standard Phase 2, helps customers acquire and finance natural gas vehicles and obtains local, state and federal 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 financial position, results of operations and cash flows as of and for the three and six months ended June 30, 2014 and 2015. All intercompany accounts and transactions have been eliminated in consolidation. The three and six month periods ended June 30, 2014 and 2015 are not necessarily indicative of the results to be expected for the year ending December 31, 2015 or for any other interim period or for any future year.

Certain information and disclosures normally included in the notes to the 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 (“US GAAP”) as they apply to interim reporting. The condensed consolidated financial statements should be read in conjunction with the consolidated financial statements as of and for the year ended December 31, 2014 that are included in the Company’s Annual Report on Form 10-K filed with the SEC on February 26, 2015.

Use of Estimates: The preparation of condensed consolidated financial statements in conformity with US GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the condensed consolidated financial statements and revenues and expenses recorded during the reporting period. Actual results could differ from those estimates. Significant estimates made in preparing the condensed consolidated financial statements include (but are not limited to) those related to revenue recognition, warranty reserves, goodwill and long-lived intangible asset valuations and impairment assessments, income tax valuations, and stock-based compensation expense.

Note 2— Acquisition and Divestitures

NG Advantage

On October 14, 2014, the Company entered a Common Unit Purchase Agreement (“UPA”) with NG Advantage, LLC (“NG Advantage”). NG Advantage is engaged in the business of transporting CNG in high-capacity trailers to large industrial and institutional energy users, such as hospitals, food processors, manufacturers and paper mills, which do not have direct access to natural gas pipelines. The Company viewed the acquisition as a strategic investment in the expansion of the Company’s initiative to deliver natural gas to industrial and institutional energy users. Under the terms of the UPA, the Company paid NG Advantage $37,650 for a 53.3% controlling interest in NG Advantage. $19,000 of the purchase price was paid in cash on October 14, 2014 and the remaining $18,650 of the purchase price was paid in the form of an unsecured promissory note issued by the Company (the “NG Advantage Note”). The principal amount of the NG Advantage Note was payable by the Company in two payments as follows: (i) $3,000 was paid January 13, 2015 and (ii) the remaining $15,650 was paid April 1, 2015. The NG Advantage Note did not bear interest. The fair value of the NG Advantage Note delivered to NG Advantage is excluded from the Company’s consolidated statements of cash flows as it is a non-cash investing activity. The consideration paid is accounted for as an intercompany transaction, as NG Advantage’s financial results are included in the Company’s condensed consolidated financial statements.

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The Company accounted for this acquisition in accordance with Financial Accounting Standards Board (“FASB”) authoritative guidance for business combinations, which requires the Company to recognize the assets acquired and the liabilities assumed, measured at their fair values, as of the date of acquisition. The following table summarizes the allocation of the aggregate purchase price to the preliminary fair value of the assets acquired and liabilities assumed:

Current assets	$	40,558
Property, plant and equipment	20,862
Other long-term assets	5,115
Identifiable intangible assets	5,600
Goodwill	21,070
Total assets acquired	93,205
Current liabilities assumed	(9,165		)
Long-term debt including capital leases assumed, excluding current installments	(17,604		)
Other liabilities	(711		)
Non-controlling interest	(28,075		)
Total purchase price	$	37,650

In connection with its purchase of a controlling interest in NG Advantage, the Company assumed debt of $20,439 on a consolidated basis related to purchases of capital assets and working capital needs. Immediately after the Company’s purchase of the controlling interest, $10,361 of such debt was paid with proceeds of the Company’s investment in NG Advantage, and the related debt instruments were cancelled.

Management allocated approximately $5,600 of the purchase price to the identifiable intangible assets related to customer relationships and trade names that were acquired with the acquisition. The fair value of the identifiable intangible assets will be amortized on a straight-line basis over the estimated useful lives of such assets ranging from four to seven years. The excess of the purchase price over the fair value of net assets acquired was allocated to goodwill, which primarily represents additional market share available to the Company as a result of the acquisition, and is fully deductible for income tax purposes.

Management determined the fair value of the non-controlling interest to be $28,075 using a market approach and using inputs that included use of a comparable transaction to calculate the value of the non-controlling interest adjusted for a control premium.

The results of NG Advantage’s operations have been included in the Company’s consolidated financial statements since October 14, 2014. The historical results of NG Advantage’s operations were not material to the Company’s financial position or historical results of operations.

DCE and DCEMB

On September 4, 2014, Mavrix, LLC (“Mavrix”), a wholly owned subsidiary of the Company, sold to Cambrian Energy McCommas Bluff III LLC (“Cambrian”) 19% of its then-70% interest in Dallas Clean Energy, LLC (“DCE”). On December 29, 2014, Mavrix entered into a Membership Interest Purchase Agreement (the “Agreement”) with Cambrian, pursuant to which Mavrix sold to Cambrian its entire remaining 51% interest in DCE. DCE owns all of the equity interests in Dallas Clean Energy McCommas Bluff, LLC (“DCEMB”), which owns a renewable natural gas extraction and processing project at the McCommas Bluff landfill in Dallas, Texas. As consideration for the sale of DCE, the Company, through Mavrix, received $6,992 in cash in September 2014 and $40,588 in cash in December 2014 and may receive up to an additional $1,250 in cash, subject to the results of certain performance tests to be performed at the McCommas Bluff project in accordance the terms of the Agreement. The Company will continue to have the right to market and sell biomethane produced at the McCommas Bluff project under its Redeem™ renewable natural gas vehicle fuel brand. The transaction resulted in a gain of $11,998 that was recorded in the line item gain from the sale of subsidiary in the Company’s consolidated statement of operations for the year ended December 31, 2014. Included in the determination of the gain was goodwill of $7,205 that was allocated to the transaction in accordance with FASB authoritative guidance for subsequent measure of goodwill which requires the Company to allocate goodwill to the disposed business based on the relative fair values of the business disposed and the portion of the reporting unit that was retained.

The Company determined, in accordance with FASB authoritative guidance, that the disposal did not meet the definition of a discontinued operation as the disposal did not represent a significant disposal nor was the disposal a strategic shift in the Company’s strategy.

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Note 3—Cash and Cash Equivalents

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 investments may be in excess of the Federal Deposit Insurance Corporation (“FDIC”), Canadian Deposit Insurance Corporation (“CDIC”), and other foreign insurance limits. Financial instruments that potentially subject the Company to concentrations of credit risk consist principally of cash deposits. The amounts in excess of FDIC, CDIC, and other foreign insurance limits were approximately $88,740 and $50,117 as of December 31, 2014 and June 30, 2015, respectively.

Note 4—Restricted Cash

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. Restricted cash consisted of the following as of December 31, 2014 and June 30, 2015:

	December 31, 2014		June 30, 2015
Short-term restricted cash:
Standby letters of credit	$	1,753	$	1,753
Canton bonds — current operating costs	4,259		2,716
Total short-term restricted cash	$	6,012	$	4,469

Note 5—Investments

Available-for-sale investments are carried at fair value, inclusive of unrealized gains and losses. Net unrealized gains and losses are included in other comprehensive income (loss) net of applicable income taxes. Gains or losses on sales of available-for-sale investments are recognized on the specific identification basis. All of the Company’s short-term investments are classified as available-for-sale securities.

The Company reviews available-for-sale investments for other-than-temporary 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. This evaluation is based on a number of factors, including the length of time and the extent to which the fair value has been below its cost basis and adverse conditions related specifically to the security, including any changes to the credit rating of the security. As of June 30, 2015, the Company believes its carrying values for its available-for-sale investments are properly recorded.

Short-term investments as of December 31, 2014 are summarized as follows:

	Amortized Cost		Gross Unrealized Losses			Estimated Fair Value
Municipal bonds & notes	$	38,668	$	(16	)	$	38,652
Zero coupon bonds	3,308		(2		)	3,306
Corporate bonds	45,274		(41		)	45,233
Certificate of deposits	35,355		—			35,355
	$	122,605	$	(59	)	$	122,546

Short-term investments as of June 30, 2015 are summarized as follows:

	Amortized Cost		Gross Unrealized Gains/(Losses)			Estimated Fair Value
Municipal bonds & notes	$	38,825	$	(24	)	$	38,801
Zero coupon bonds	5,013		3			5,016
Corporate bonds	38,850		(24		)	38,826
Certificate of deposits	45,953		—			45,953
	$	128,641	$	(45	)	$	128,596

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Note 6—Other Receivables

Other receivables at December 31, 2014 and June 30, 2015 consisted of the following:

	December 31, 2014		June 30, 2015
Loans to customers to finance vehicle purchases	$	8,257	$	8,982
Accrued customer billings	10,143		5,730
Fuel tax and carbon credits	34,250		155
Other	3,573		3,789
	$	56,223	$	18,656

Note 7—Inventories

Inventory consists of work in process and finished goods and is stated at the lower of cost (first-in, first-out) or market. The Company writes down the carrying value of its inventory to net realizable value for estimated obsolescence or unmarketable inventory in an amount equal to the difference between the cost of inventory and its estimated realizable value based upon assumptions about future demand and market conditions, among other factors.

Inventories consisted of the following as of December 31, 2014 and June 30, 2015:

	December 31, 2014		June 30, 2015
Raw materials and spare parts	$	31,389	$	28,080
Work in process	3,292		1,879
Finished goods	15		1,388
	$	34,696	$	31,347

Note 8—Land, Property and Equipment

Land, property and equipment at December 31, 2014 and June 30, 2015 are summarized as follows:

	December 31, 2014			June 30, 2015
Land	$	2,858		$	2,858
LNG liquefaction plants	94,636			94,636
RNG plants	45,359			45,451
Station equipment	265,086			293,851
Trailers	40,067			50,355
Other equipment	74,796			79,929
Construction in progress	163,737			146,431
	686,539			713,511
Less: accumulated depreciation	(172,270		)	(193,087		)
	$	514,269		$	520,424

Included in land, property and equipment are capitalized software costs of $21,004 and $21,558 as of December 31, 2014 and June 30, 2015, respectively. The accumulated amortization on the capitalized software costs is $10,740 and $12,287 as of December 31, 2014 and June 30, 2015, respectively. The Company recorded $843 and $831 of amortization expense related to the capitalized software costs during the three months ended June 30, 2014 and June 30, 2015, respectively. For the six month periods ended June 30, 2014 and 2015, the Company recorded $1,611 and $1,547 of amortization expense related to the capitalized software costs respectively.

As of June 30, 2014 and June 30, 2015, $16,360 and $9,720, respectively are included in accounts payable and accrued liabilities balances, which amounts are related to purchases of property and equipment. These amounts are excluded from the condensed consolidated statements of cash flows as they are non-cash investing activities.

Note 9—Investments in Other Entities

On September 16, 2014, the Company formed a joint venture with Mansfield Ventures LLC (“Mansfield”) called Mansfield Clean Energy Partners LLC (“MCEP”), which is designed to provide natural gas fueling solutions to bulk fuel haulers in the U.S. The Company and Mansfield each have a 50% ownership interest in MCEP. The Company accounts for its interest using the equity method of accounting, as the Company has the ability to exercise significant influence over MCEP’s operations. The Company recorded a loss from this investment of $345 and $549 for the three and six months ended June 30, 2015, respectively and has an investment balance of $4,961 at June 30, 2015.

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Note 10—Accrued Liabilities

Accrued liabilities at December 31, 2014 and June 30, 2015 consisted of the following:

	December 31, 2014		June 30, 2015
Salaries and wages	$	9,041	$	8,206
Accrued gas and equipment purchases	12,340		15,904
Accrued property and other taxes	5,178		7,199
Accrued professional fees	1,084		742
Accrued employee benefits	3,208		4,125
Accrued warranty liability	2,302		2,423
Accrued interest	3,748		3,721
Other	19,859		9,007
	$	56,760	$	51,327

Note 11—Warranty Liability

The Company records warranty liabilities at the time of sale for the estimated costs that may be incurred under its standard warranty. Changes in the warranty liability are presented in the following table:

	June 30, 2014			June 30, 2015
Warranty liability at beginning of year	$	2,545		$	2,302
Costs accrued for new warranty contracts and changes in estimates for pre-existing warranties	2,455			1,220
Service obligations honored	(1,685		)	(1,099		)
Warranty liability at end of period	$	3,315		$	2,423

Note 12—Long-Term Debt

7.5% Notes

On July 11, 2011, the Company entered into a loan agreement (the “CHK Agreement”) with Chesapeake NG Ventures Corporation (“Chesapeake”), an indirect wholly owned subsidiary of Chesapeake Energy Corporation, whereby Chesapeake agreed to purchase from the Company up to $150,000 of debt securities (the “CHK Financing”) pursuant to the issuance of three convertible promissory notes, each having a principal amount of $50,000 (each a “CHK Note” and collectively the “CHK Notes” and, together with the CHK Agreement and other transaction documents, the “CHK Loan Documents”). The first CHK Note was issued on July 11, 2011 and the second CHK Note was issued on July 10, 2012.

On June 14, 2013 (the “Transfer Date”), Boone Pickens and Green Energy Investment Holdings, LLC, an affiliate of Leonard Green & Partners, L.P. (collectively, the “Buyers”), and Chesapeake entered into a note purchase agreement (“Note Purchase Agreement”) pursuant to which Chesapeake sold the outstanding CHK Notes (the “Sale”) to the Buyers. Chesapeake assigned to the Buyers all of its right, title and interest under the CHK Loan Documents (the “Assignment”), and each Buyer severally assumed all of the obligations of Chesapeake under the CHK Loan Documents arising after the Sale and the Assignment including, without limitation, the obligation to advance an additional $50,000 to the Company in June 2013 (the “Assumption”). The Company also entered into the Note Purchase Agreement for the purpose of consenting to the Sale, the Assignment and the Assumption.

Contemporaneously with the execution of the Note Purchase Agreement, the Company entered into a loan agreement with each Buyer (collectively, the “Amended Agreements”). The Amended Agreements have the same terms as the CHK Agreement, other than changes to reflect the change in ownership of the CHK Notes. Immediately following execution of the Amended Agreements, the Buyers delivered $50,000 to the Company in satisfaction of the funding requirement they had assumed from Chesapeake (the “June Advance”). In addition, the Company cancelled the existing CHK Notes and re-issued replacement notes, and the Company also issued notes to the Buyers in exchange for the June Advance (the re-issued replacement notes and the notes issued in exchange for the June Advance are referred to herein as the “7.5% Notes”).

The 7.5% Notes have the same terms as the original CHK Notes, other than the changes to reflect their different holders. They bear interest at the rate of 7.5% per annum and are convertible at the option of the holder into shares of the Company’s common stock at a conversion price of $15.80 per share (the “7.5% Notes Conversion Price”). Upon written notice to the Company, the holders of the 7.5% Notes have the right to exchange all or a portion of the principal and accrued and unpaid interest under each such note for shares of the Company’s common stock at the 7.5% Notes Conversion Price. Additionally, subject to certain restrictions, the Company can force conversion of each 7.5% Note into shares of the its common stock if, following the second anniversary of the issuance of a

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7.5% Note, such shares trade at a 40% premium to the 7.5% Notes Conversion Price for at least 20 trading days in any consecutive 30 trading day period. The entire principal balance of each 7.5% Note is due and payable seven years following its issuance and the Company may repay each 7.5% Note in shares of its common stock or cash. All of the shares issuable upon exercise of the 7.5% Notes have been registered for resale by their holders pursuant to a registration statement that has been filed with and declared effective by the Securities and Exchange Commission. The Amended Agreements restrict the use of the proceeds of the 7.5% Notes to financing the development, construction and operation of LNG stations and payment of certain related expenses. The Amended Agreements also provide for customary events of default which, if any of them occurs, would permit or require the principal of, and accrued interest on, the 7.5% Notes to become, or to be declared, due and payable. No events of default under the 7.5% Notes had occurred as of June 30, 2015.

On August 27, 2013, Green Energy Investment Holdings, LLC transferred $5,000 in principal amount of the 7.5% Notes to certain third parties.

As a result of the foregoing transactions, (i) Mr. Pickens holds 7.5% Notes in the aggregate principal amount of $65,000, which 7.5% Notes are convertible into approximately 4,113,924 shares of the Company’s common stock, and (ii) Green Energy Investment Holdings, LLC holds 7.5% Notes in the aggregate principal amount of $80,000, which 7.5% Notes are convertible into approximately 5,063,291 shares of the Company’s common stock.

At June 30, 2015, none of the proceeds from the 7.5% Notes were included in restricted cash as the Company had used the funds primarily to build LNG fueling stations.

SLG Notes

On August 24, 2011, the Company entered into convertible note purchase agreements (each, an “SLG Agreement” and collectively the “SLG Agreements”) with each of Springleaf Investments Pte. Ltd., a wholly-owned subsidiary of Temasek Holdings Pte. Ltd., Lionfish Investments Pte. Ltd., an investment vehicle managed by Seatown Holdings International Pte. Ltd., and Greenwich Asset Holding Ltd., a wholly-owned subsidiary of RRJ Capital Master Fund I, L.P. (each, a “Purchaser” and collectively, the “Purchasers”), whereby the Purchasers agreed to purchase from the Company $150,000 of 7.5% convertible notes due in August 2016 (each a “SLG Note” and collectively the “SLG Notes”). The transaction closed and the SLG Notes were issued on August 30, 2011. On March 1, 2012, Springleaf Investments Pte. LTD transferred $24,000 principal amount of the SLG Notes to Baytree Investments (Mauritius) Pte. Ltd.

The SLG Notes bear interest at the rate of 7.5% per annum and are convertible at each Purchaser’s option into shares of the Company’s common stock at a conversion price of $15.00 per share (the “SLG Conversion Price”). Upon written notice to the Company, the holders of the SLG Notes have the right to exchange all or any portion of the principal and accrued and unpaid interest under each such note for shares of the Company’s common stock at the SLG Conversion Price. Additionally, subject to certain restrictions, the Company can force conversion of each SLG Note into shares of its common stock if, following the second anniversary of the issuance of the SLG Notes, such shares trade at a 40% premium to the SLG Conversion Price for at least 20 trading days in any consecutive 30 trading day period. The entire principal balance of each SLG Note is due and payable five years following its issuance, and the Company may repay the principal balance of each SLG Note in shares of its common stock or cash. All of the shares issuable upon exercise of the SLG Notes have been registered for resale by their holders pursuant to a registration statement that has been filed with and declared effective by the Securities and Exchange Commission. The SLG Agreements provide for customary events of default which, if any of them occurs, would permit or require the principal of, and accrued interest on, the SLG Notes to become, or to be declared, due and payable. No events of default under the SLG Notes had occurred as of June 30, 2015.

In April 2012, $1,003 of principal and accrued interest under an SLG Note was converted by the holder thereof into 66,888 shares of the Company’s common stock. In January and February 2013, $4,030 of principal and accrued interest under an SLG Note was converted by the holder thereof into 268,664 shares of the Company’s common stock.

GE Loans

On November 7, 2012, the Company, through two wholly owned subsidiaries (the “Borrowers”), entered into a credit agreement (“Credit Agreement”) with General Electric Capital Corporation (“GE”). Pursuant to the Credit Agreement, GE agreed to loan to the Borrowers up to an aggregate of $200,000 to finance the development, construction and operation of two LNG plants (individually a “Project” and together the “Projects”).

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On December 29, 2014, the Borrowers and GE entered into an amendment to the Credit Agreement providing, among other things, that (i) the Credit Agreement will terminate if the initial loans under the Credit Agreement (collectively, “Loans” and, with respect to each Project “Tranche A Loans” and “Tranche B Loans”) for the Projects are not made prior to December 31, 2016 (rather than December 31, 2014, as the Credit Agreement originally provided), (ii) each Project must be completed by the earlier of (a) the date that is thirty months after the funding of the initial Loans with respect to such Project and (b) December 31, 2018 (rather than December 31, 2016, as the Credit Agreement originally provided) (with respect to each Project, the “Date Certain”), and (iii) prior to the funding of the Loans, the Borrowers will be required to enter into agreements with GE Oil & Gas, Inc. relating to the purchase of equipment for the Projects.

The Borrowers’ ability to obtain the Loans under the Credit Agreement is subject to the satisfaction of certain conditions, including each of the (i) acquisition of title to, or leasehold interests in, the sites upon which the Projects will be constructed, (ii) receipt of all governmental approvals necessary in connection with the design, development, ownership, construction, installation, operation and maintenance of the Projects, and (iii) commitment of all utility services necessary for the construction and operation of the Projects.

The Credit Agreement further provides that (i) the then existing Loans with respect to each Project must be converted into term loans with eight year amortization schedules (“Term Loans”) on or before the Date Certain with respect to such Project (the date of such conversion with respect to each Project, the “Conversion Date”), provided that if such Loans are not converted into Term Loans by the applicable Date Certain, such Loans must be repaid by the applicable Date Certain, (ii) each Term Loan will be due and payable on the eighth anniversary of the Conversion Date with respect to such Term Loan, and (iii) at any time prior to the applicable Conversion Date, the Loans may be prepaid in whole, and at any time after the applicable Conversion Date, the Loans may be prepaid in whole or in part. The Company expects the Loans to bear interest at an annual rate equal to the then- current LIBOR rate plus 7.00%, provided that for purposes of the Credit Agreement, the then-current LIBOR rate will always be at least 1.00%. The Credit Agreement includes various customary covenants, including debt service coverage ratios and a commitment fee on the unutilized loan amounts of 0.5% per annum, and also provides for customary events of default which, if such events occur, would permit or require the Loans to become or to be declared due and payable. As of June 30, 2015, the Company has not drawn any money under the Credit Agreement and was in compliance with the financial covenants. The commitment fee, which is charged to interest expense in the condensed consolidated statements of operations, was $253 for each of the three months ended June 30, 2014 and 2015, respectively. For the six month periods ended June 30, 2014 and 2015, the Company recorded $503 of interest expense for each period related to the commitment fee.

The Loans are secured by (i) a first priority security interest in all of the Borrowers’ assets, including the Projects, and (ii) a pledge of the Borrowers’ outstanding ownership interests. In addition, the Company has executed a guaranty in favor of GE (“Guaranty”), pursuant to which the Company has guaranteed all of the Borrowers’ obligations under the Credit Agreement, including repayment of all Loans.

The Company and GE also entered an equity contribution agreement (the “EC Agreement”) pursuant to which the Company agreed to pay at least 25% of the budgeted cost of the Projects and all additional costs that exceed such expected budgeted costs, in each case, in the form of equity contributions to the Borrowers (“Equity Contributions”). The EC Agreement also requires the Company to provide, concurrent with GE’s extension of the initial Loans under the Credit Agreement, letter(s) of credit in an amount equal to the Company’s then-current unfunded Equity Contributions.

Concurrently with the execution of the Credit Agreement, the Company issued to GE a warrant to purchase up to five million shares of its common stock (see note 13).

5.25% Notes

In September 2013, the Company completed a private offering of 5.25% Convertible Senior Notes due 2018 (the “5.25% Notes”) and entered into an indenture governing the 5.25% Notes (the “Indenture”).

The net proceeds from the sale of the 5.25% Notes after the payment of certain debt issuance costs of $7,805 were $242,195. The Company has used, and intends to continue to use, the net proceeds from the sale of the 5.25% Notes to fund capital expenditures and for general corporate purposes.

The 5.25% Notes bear interest at a rate of 5.25% per annum, payable semi-annually in arrears on October 1 and April 1 of each year, beginning on April 1, 2014. The 5.25% Notes will mature on October 1, 2018, unless purchased, redeemed or converted prior to such date in accordance with their terms and the terms of the Indenture.

Holders may convert their 5.25% Notes, at their option, at any time prior to the close of business on the business day immediately preceding the maturity date of the 5.25% Notes. Upon conversion, the Company will deliver a number of shares of its common stock, per $1 principal amount of 5.25% Notes, equal to the conversion rate then in effect (together with a cash payment in lieu of any fractional shares). The initial conversion rate for the 5.25% Notes is 64.1026 shares of the Company’s common stock per $1 principal amount of Notes (which is equivalent to an initial conversion price of approximately $15.60 per share of the Company’s common stock). The conversion rate is subject to adjustment upon the occurrence of certain specified events as described in the Indenture.

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Upon the occurrence of certain corporate events prior to the maturity date of the 5.25% Notes, the Company will, in certain circumstances, in addition to delivering the number of shares of the Company’s common stock deliverable upon conversion of the 5.25% Notes based on the conversion rate then in effect (together with a cash payment in lieu of any fractional shares), pay holders that convert their 5.25% Notes a cash make-whole payment in an amount as described in the Indenture. The Company may, at its option, irrevocably elect to settle its obligation to pay any such make-whole payment in shares of its common stock instead of in cash. The amount of any make-whole payment, whether it is settled in cash or in shares of the Company’s common stock upon the Company’s election, will be determined based on the date on which the corporate event occurs or becomes effective and the stock price paid (or deemed to be paid) per share of the Company’s common stock in the corporate event, as described in the Indenture.

The Company may not redeem the 5.25% Notes prior to October 5, 2016. On or after October 5, 2016, the Company may, at its option, redeem for cash all or any portion of the 5.25% Notes if the closing sale price of the Company’s common stock for at least 20 trading days (whether or not consecutive) during any 30 consecutive trading day period ending on, and including, the trading day immediately preceding the date on which notice of redemption is provided, exceeds 160% of the conversion price on each applicable trading day. In the event of the Company’s redemption of the 5.25% Notes, the redemption price will equal 100% of the principal amount of the 5.25% Notes to be redeemed, plus accrued and unpaid interest to, but excluding, the redemption date. No sinking fund is provided for in the 5.25% Notes.

If the Company undergoes a fundamental change (as defined in the Indenture) prior to the maturity date of the 5.25% Notes, subject to certain conditions as described in the Indenture, holders may require the Company to purchase, for cash, all or any portion of their 5.25% Notes at a repurchase price equal to 100% of the principal amount of the 5.25% Notes to be repurchased, plus accrued and unpaid interest to, but excluding, the fundamental change purchase date.

The Indenture contains customary events of default with customary cure periods, including, without limitation, failure to make required payments or deliveries of shares of the Company’s common stock when due under the Indenture, failure to comply with certain covenants under the Indenture, failure to pay when due or acceleration of certain other indebtedness of the Company or certain of its subsidiaries, and certain events of bankruptcy and insolvency of the Company or certain of its subsidiaries. The occurrence of an event of default under the Indenture will allow either the trustee or the holders of at least 25% in principal amount of the then-outstanding 5.25% Notes to accelerate, or upon an event of default arising from certain events of bankruptcy or insolvency of the Company, will automatically cause the acceleration of, all amounts due under the 5.25% Notes. No events of default under the 5.25% Notes had occurred as of June 30, 2015.

The 5.25% Notes are senior unsecured obligations of the Company and rank senior in right of payment to the Company’s future indebtedness that is expressly subordinated in right of payment to the 5.25% Notes; equal in right of payment to the Company’s unsecured indebtedness that is not so subordinated; effectively junior to any of the Company’s secured indebtedness to the extent of the value of the assets securing such indebtedness; and structurally junior to all indebtedness (including trade payables) of the Company’s subsidiaries.

Canton Bonds

On March 19, 2014, Canton Renewables, LLC (“Canton”), a wholly owned subsidiary of the Company, completed the issuance of Solid Waste Facility Limited Obligation Revenue Bonds (Canton Renewables, LLC — Sauk Trail Hills Project) Series 2014 in the aggregate principal amount of $12,400 (the “Bonds”).

The Bonds were issued by the Michigan Strategic Fund (the “Issuer”) and the proceeds of such issuance were loaned by the Issuer to Canton pursuant to a loan agreement that became effective on March 19, 2014 (the “Loan Agreement”). The Bonds are expected to be repaid from revenue generated by Canton from the sale of RNG and are secured by the revenue and assets of Canton. The Bond repayments will be amortized through July 1, 2022, the average coupon interest rate on the Bonds is 6.6%, and all but $1,000 of the principal amount of the Bonds is non-recourse to Canton’s parent companies, including the Company.

Canton used the Bond proceeds primarily to (i) refinance the cost of constructing and equipping its RNG extraction and production project in Canton, Michigan and (ii) pay a portion of the costs associated with the issuance of the Bonds. The refinancing described in the prior sentence was accomplished through distributions to the Borrower’s direct and indirect parent companies who provided the financing for the RNG production facility, and such companies have used such distributions to finance construction of additional RNG extraction and processing projects and for working capital purposes.

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The Loan Agreement contains customary events of default, with customary cure periods, including without limitation, failure to make required payments when due under the Loan Agreement, failure to comply with certain covenants under the Loan Agreement, certain events of bankruptcy and insolvency of Canton, and the existence of an event of default under the indenture governing the Bonds that was entered between the Issuer and The Bank of New York Mellon Trust Company, N.A., as trustee. The occurrence of an event of default under the Loan Agreement will allow the Issuer or the trustee to accelerate all amounts due under the Loan Agreement. No events of default under the Loan Agreement had occurred as of June 30, 2015.

Other Debt

The Company has other debt due at various dates through 2020 bearing interest at rates up to 15.49% and with a weighted average interest rate of 6.80% and 6.67% as of December 31, 2014 and June 30, 2015, respectively.

Long-term debt and capital lease obligations at December 31, 2014 and June 30, 2015 consisted of the following:

	December 31, 2014			June 30, 2015
7.5% Notes	$	150,000		$	150,000
SLG Notes	145,000			145,000
5.25% Notes	250,000			250,000
Canton Bonds ($11,400 non-recourse to the Company)	12,150			11,600
Capital lease obligations	2,692			7,754
Other debt	10,828			11,392
Total debt and capital lease obligations	570,670			575,746
Less amounts due within one year	(4,846		)	(5,977		)
Total long-term debt and capital lease obligations	$	565,824		$	569,769

Note 13—Net Loss Per Share

Basic net loss per share is based upon the weighted-average number of shares outstanding and issuable for little or no cash consideration during each period. Diluted net loss per share reflects the impact of the assumed exercise of dilutive stock options and warrants. On September 11, 2014, the Company determined it no longer met certain conditions required to include in its weighted average share calculations 4,000,000 of the 5,000,000 shares of common stock issuable upon exercise of a warrant issued to GE concurrently with the execution of the Credit Agreement (the “GE Warrant”). As a result, since September 11, 2014, the Company has (i) excluded 4,000,000 shares of common stock issuable upon exercise of the GE Warrant from the weighted average number of shares outstanding in the basic and diluted earnings per share calculations, and (ii) included the remaining 1,000,000 shares of common stock issuable upon exercise of the GE Warrant in the basic and diluted earnings per share calculations, as 500,000 shares issuable upon exercise of the GE Warrant were exercisable as of the execution of the Credit Agreement and an additional 500,000 shares issuable upon exercise of the GE Warrant became exercisable on December 31, 2014. The information required to compute basic and diluted earnings per share is as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2014	2015	2014	2015
Basic and diluted:
Weighted average number of common shares outstanding	94,859,587	91,480,998	94,768,462	91,399,478

Certain securities were excluded from the diluted earnings per share calculations for the three and six months ended June 30, 2014 and 2015, respectively, as the inclusion of the securities would be anti-dilutive to the calculations. The amounts of these securities that were outstanding as of June 30, 2014 and 2015 for these instruments are as follows:

	June 30,
	2014	2015
Options	11,858,681	10,782,668
Warrants	2,130,682	6,130,682
Convertible Notes	35,185,979	35,185,979
Restricted Stock Units	2,080,336	2,972,252

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Note 14—Stock-Based Compensation

The following table summarizes the compensation expense and related income tax benefit related to the stock-based compensation expense recognized during the periods:

	Three Months Ended June 30,				Six Months Ended June 30,
	2014		2015		2014		2015

Stock-based compensation expense	$	2,978	$	2,663	$	6,398	$	5,353
Stock-based compensation expense, net of tax	$	2,978	$	2,663	$	6,398	$	5,353

Stock Options

The following table summarizes the Company’s stock option activity during the six months ended June 30, 2015:

	Number of Shares		Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (in years)	Aggregate Intrinsic Value
Outstanding, December 31, 2014	11,486,301		$	11.91
Options granted	465,000		6.15
Options exercised	(607,500	)	2.96
Options forfeited	(561,133	)	14.13
Outstanding, June 30, 2015	10,782,668		$	12.05	5.01	$	—
Exercisable, June 30, 2015	9,340,463		$	12.48	4.43	$	—

As of June 30, 2015, there was $4,979 of total unrecognized compensation cost related to non-vested shares underlying outstanding stock options. That cost is expected to be recognized over a weighted average period of 1.6 years. The total fair value of shares vested during the six months ended June 30, 2015 was $4,314.

The Company is obligated to issue shares of its common stock upon the exercise of outstanding stock options. The intrinsic value of all stock options exercised during the six months ended June 30, 2014 and 2015 was $1,419 and $2,196, respectively.

The fair value of each stock option granted during the six months ended June 30, 2015 was estimated as of the date of grant using the Black-Scholes option pricing model and the following assumptions:

		Six Months Ended June 30, 2015
Dividend yield		0.00%
Expected volatility		59.2% to 61.5%
Risk-free interest rate		1.7% to 1.8%
Expected life in years		6.0

The weighted-average grant date fair values of stock options granted during the six months ended June 30, 2014 and 2015 was $5.99 and $3.42, respectively. The volatility amounts used during these periods were estimated based on the Company’s historical volatility and the Company’s implied volatility of its traded options for such periods. The expected lives used during the periods were based on historical exercise periods and the Company’s anticipated exercise periods for its outstanding stock options. The risk free rates used during the periods were based on the U.S. Treasury yield curve for the expected life of the stock options at the time of grant. The Company recorded $3,819 and $2,843 of stock option expense during the six months ended June 30, 2014 and 2015, respectively. The Company has not recorded any tax benefit related to its stock option expense.

Market-Based Restricted Stock Units

The Company issued market-based restricted stock units (“Market-Based RSUs”) to certain key employees during 2012 and 2014. A holder of Market-Based RSUs will receive one share of the Company’s common stock for each Market-Based RSU held if (i) between two years and four years from the date of grant of the Market-Based RSU, the closing price of the Company’s common stock equals or exceeds, for twenty consecutive trading days, 135% of the closing price of the Company’s common stock on the Market-Based RSU grant date (the “Stock Price Condition”) and (ii) the holder is employed by the Company at the time the Stock Price Condition is satisfied. If the Stock Price Condition is not satisfied prior to four years from the date of grant, the Market-Based RSUs will be automatically forfeited. The Market-Based RSUs are subject to the terms and conditions of the Company’s Amended and Restated 2006 Equity Incentive Plan (the “2006 Plan”) and a Notice of Grant of Restricted Stock Unit and Restricted Stock Unit Agreement.

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The following table summarizes the Company’s Market-Based RSU activity during the six months ended June 30, 2015:

	Number of Shares	Weighted Average Fair Value at Grant Date		Weighted Average Remaining Contractual Term (in years)
Outstanding, December 31, 2014	1,769,000	$	10.67
RSUs granted	—	—
Outstanding and non-vested, June 30, 2015	1,769,000	$	10.67	1.1

As of June 30, 2015, there was $1,180 of total unrecognized compensation cost related to non-vested shares underlying outstanding Market-Based RSUs. That cost is expected to be recognized over a weighted average period of 0.6 year.

The Company recorded $1,775 and $885 of expense during the six months ended June 30, 2014 and 2015, respectively, related to the Market-Based RSUs. The Company has not recorded any tax benefit related to its Market-Based RSU expense.

Service-Based Restricted Stock Units

The Company has issued service-based restricted stock units (“Service-Based RSUs”) to certain employees that vest annually over the three years following the date of issuance at a rate of 34%, 33% and 33%, respectively, if the holder is in service to the Company at each vesting date. The Service- Based RSUs are subject to the terms and conditions of the Company’s 2006 Plan and a Notice of Grant of Restricted Stock Unit and Restricted Stock Unit Agreement.

The following table summarizes the Company’s Service-Based RSU activity during the six months ended June 30, 2015:

	Number of Shares		Weighted Average Fair Value at Grant Date		Weighted Average Remaining Contractual Term (in years)
Non-vested at December 31, 2014	822,752		$	5.82
RSUs granted	419,500		6.05
RSUs vested	—		—
RSUs forfeited	(39,000	)	5.58
Outstanding and non-vested at June 30, 2015	1,203,252		$	5.91	2.5

As of June 30, 2015, there was $5,643 of total unrecognized compensation cost related to non-vested shares underlying outstanding Service-Based RSUs. That cost is expected to be recognized evenly over a period of 2.4 years.

The Company recorded $153 and $1,050 of expense during the six months ended June 30, 2014 and 2015, respectively related to the Service-Based RSUs. The Company has not recorded any tax benefit related to its Service-Based RSU expense.

The fair value of each Service-Based RSU granted during the three months ended June 30, 2015 was estimated using the closing stock price of the Company’s common stock on the date of grant.

Employee Stock Purchase Plan

On May 7, 2013, the Company adopted an employee stock purchase plan (the “ESPP”), pursuant to which eligible employees may purchase shares of the Company’s common stock at 85% of the fair market value of the common stock on the last trading day of two consecutive, non-concurrent offering periods each year. The Company has reserved 2,500,000 shares of its common stock for issuance under the ESPP.

The Company recorded $37 and $25 of expense related to the ESPP during the six months ended June 30, 2014 and 2015, respectively. The Company has not recorded any tax benefits related to its ESPP expense. At June 30, 2015, the Company had sold an aggregate of 105,257 shares pursuant to the ESPP.

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Non-Qualified Non-Public Subsidiary Unit Options

In September 2013, the Company’s wholly owned subsidiary, Clean Energy Renewable Fuels, LLC (“Clean Energy Renewables”, formerly known as CERF), adopted the Clean Energy Renewable Fuels, LLC 2013 Unit Option Plan (the “Clean Energy Renewables Plan”). 150,000 Class B units representing membership interests in Clean Energy Renewables were initially reserved for issuance under the Clean Energy Renewables Plan.

The following table summarizes Clean Energy Renewables’ unit option activity during the six months ended June 30, 2015:

	Number of Units		Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (in years)	Aggregate Intrinsic Value
Outstanding, December 31, 2014	115,000		$	40.80
Options granted	—		—
Options exercised	—		—
Options forfeited	(7,000	)	40.80
Outstanding and non-vested, June 30, 2015	108,000		$	40.80	8.22	$	—

As of June 30, 2015, there was $1,384 of total unrecognized compensation cost related to non-vested units underlying outstanding options issued pursuant to the Clean Energy Renewables Plan. That cost is expected to be recognized over a weighted average period of 0.9 years.

Clean Energy Renewables recorded a total of $614 and $538 of unit option expense during the six months ended June 30, 2014 and 2015, respectively. Clean Energy Renewables has not recorded any tax benefit related to its unit option expense.

In March 2013, NG Advantage, adopted the NG Advantage LLC 2013 Unit Option Plan (the “NG Advantage Plan”). NG Advantage recorded a total of $12 of unit option expense during the six months ended June 30, 2015.

Note 15—Environmental Matters, Litigation, Claims, Commitments and Contingencies

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 which would have a material impact on the Company’s condensed 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.

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

Note 16—Income Taxes

The Company’s income tax provision for the three and six months ended June 30, 2015 was $740 and $1,594, respectively. The tax expense for the three and six months ended June 30, 2014 was $147 and $1,109 respectively. Tax expense for all periods was comprised of taxes due on the Company’s U.S. and foreign operations. The increase in the Company’s income tax provision for the six months ended June 30, 2015 as compared to the tax provision for the six months ended June 30, 2014 was primarily attributed to increase in the earnings of foreign subsidiaries. The effective tax rate for the three months and six months ended June 30, 2014 and 2015 are different from the federal statutory tax rate primarily as a result of losses for which no tax benefit has been recognized.

The Company did not record a change in its liability for unrecognized tax benefits or penalties in the three and six months ended June 30, 2014 or June 30, 2015, and the net interest incurred was immaterial for such periods.

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Note 17—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 nonrecurring 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 market participants would use in valuing the asset or liability developed based on market data obtained from sources independent of the Company. 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; 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.

During the six months ended June 30, 2015, the Company’s financial instruments consisted of available-for-sale securities, debt instruments, and its Series I warrants. For available-for-sale securities, the fair values are determined by the most recent quoted prices for identical assets in markets that are not active and quoted prices for similar assets in active markets, and thus represent Level 2 fair value measurements. The fair values of the Company’s debt instruments approximated their carrying values at December 31, 2014 and June 30, 2015. The Company uses the Black-Scholes model to value the Series I warrants. The Company believes the best method to approximate a market participant’s view of the volatility of its Series I warrants has been to use the implied volatilities of its short-term (i.e. 3 to 9 month) traded options and extrapolate the data over the remaining term of the Series I warrants, which was approximately 0.8 years as of June 30, 2015. This method has been utilized consistently in the periods presented. Given that the extrapolation beyond the term of the short-term exchange traded options is not based on observable market inputs for a significant portion of the remaining term of the warrants, the Series I warrants have been classified as a Level 3 fair value measurement.

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, 2014 and June 30, 2015, respectively:

Description	Balance at December 31, 2014		Level 1		Level 2		Level 3
Assets:
Available-for-sale securities(1):
Certificate of deposits	$	35,355	$	—	$	35,355	$	—
Municipal bonds and notes	38,652		—		38,652		—
Zero coupon bonds	3,306				3,306
Corporate bonds	45,233		—		45,233		—
Liabilities:
Series I warrants(2)	1,416		—		—		1,416

Description	Balance at June 30, 2015		Level 1		Level 2		Level 3
Assets:
Available-for-sale securities(1):
Certificate of deposits	$	45,953	$	—	$	45,953	$	—
Municipal bonds and notes	38,801		—		38,801		—
Zero coupon bonds	5,016				5,016
Corporate bonds	38,826		—		38,826		—
Liabilities:
Series I warrants(2)	833		—		—		833

(1) Included in short-term investments in the condensed consolidated balance sheets. See note 5 for further information.

(2) Included in accrued liabilities in the condensed consolidated balance sheets.

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The following tables provide a reconciliation of the beginning and ending balances of items measured at fair value on a recurring basis in the table above that used significant unobservable inputs (Level 3).

Liabilities: Series I Warrants	June 30, 2014			June 30, 2015
Beginning Balance	$	7,164		$	1,416
Total gain included in earnings	(2,169		)	(583		)
Ending Balance	$	4,995		$	833

Valuation Processes for Level 3 Fair Value Measurements and Sensitivity to Changes in Significant Unobservable Inputs

Fair value measurements of liabilities, which fall within Level 3 of the fair value hierarchy, are determined by the Company’s accounting department, who report to the Company’s Chief Financial Officer. The fair value measurements are compared to those of the prior reporting periods to ensure that changes are consistent with expectations of management based upon the sensitivity and nature of the inputs.

Series I Warrant Liability

The Company estimated the fair value of its Series I warrant liability using the Black-Scholes model based on the following inputs as of June 30, 2015:

Unobservable Input		Range or Weighted Average
Current market price of the Company’s common stock		$5.62
Exercise price of the warrant		$12.68
Dividend yield		0.00%
Remaining term of the warrant		0.83
Implied volatility of the Company’s common stock		80.36%
Assumed discount rate		Simple average of 0.28%

Significant changes in any of those inputs in isolation can result in a significant change in the fair value measurement. Generally, a positive change in the market price of the Company’s common stock, an increase in the volatility of the Company’s common stock, or an increase in the remaining term of the warrants would result in a directionally similar change in the estimated fair value of the Company’s Series I warrants and thus an increase in the associated liability. An increase in the assumed discount rate or a decrease in the positive differential between the warrant’s exercise price and the market price of the Company’s common stock would result in a decrease in the estimated fair value measurement of the Series I warrants and thus a decrease in the associated liability. The Company has not, nor does it plan to, declare dividends on its common stock, and thus, there is no directionally similar change in the estimated fair value of the Series I warrants due to the dividend assumption.

Non-Financial Assets

No impairments of long-lived assets measured at fair value on a non-recurring basis have been incurred during the six months ended June 30, 2014 and 2015. The Company’s use of these non-financial assets does not differ from their highest and best use as determined from the perspective of a market participant.

Note 18—Recently Adopted Accounting Changes and Recently Issued Accounting Standards

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers, amending revenue recognition guidance and requiring more detailed disclosures to enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The guidance is effective for annual and interim reporting periods beginning after December 15, 2016, with early adoption prohibited. The FASB decided on July 9, 2015 to defer the effective date of the new revenue standard by one year. As a result, this standard will be effective for fiscal years, and interim reporting periods within those years, beginning after December 15, 2017. The Company is currently evaluating the impact this ASU will have on its consolidated financial statements.

In April 2015, the FASB issued ASU No. 2015-3, Interest - Imputation of Interest, requiring that debt issuance costs be presented in the balance sheet as a deduction from the carrying amount of the related liability, rather than as a deferred charge. The updated guidance is effective retroactively for financial statements covering fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. Earlier adoption is permitted but the Company does not anticipate electing early adoption. As of June 30, 2015, the Company has $4,840 of debt issuance costs.

Note 19—Alternative Fuels Excise Tax Credit

From October 1, 2006 through December 31, 2014, the Company was eligible to receive a federal fuel tax credit (“VETC”) of $0.50 per gasoline gallon equivalent of CNG and $0.50 per liquid gallon of LNG that it sold as vehicle fuel. Based on the service relationship with its customers, either the Company or its customers claimed the credit. The Company records its VETC credits as revenue in its condensed consolidated statements of operations, as the credits are fully refundable and do not need to offset income tax liabilities to be received. VETC revenues recognized in December 2014 for the 2014 calendar year were $28,359. The Company did not recognize any VETC revenue during the three or six months ended June 30, 2015, as the program under which the Company received such credit expired December 31, 2014 and has not been renewed.

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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 “MD&A”) should be read together with the unaudited condensed consolidated financial statements and the related notes included in this report. For additional context with which to understand our financial condition and results of operations, refer to the MD&A for the fiscal year ended December 31, 2014 contained in our 2014 Annual Report on Form 10-K, which was filed with the Securities and Exchange Commission (“SEC”) on February 26, 2015, as well as the consolidated financial statements and notes contained therein (collectively, our “2014 10-K”). Unless the context indicates otherwise, all references to “Clean Energy,” the “Company,” “we,” “us,” or “our” in this MD&A and elsewhere in this report refer to Clean Energy Fuels Corp. together with its majority and wholly owned subsidiaries.

Cautionary Statement Regarding Forward Looking Statements

This MD&A and other sections of this report contain forward looking statements. We make forward-looking statements, as defined by the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995, and in some cases, you can identify these statements by forward-looking words such as “if,” “shall,” “may,” “might,” “could,” “will,” “should,” “expect,” “plan,” “anticipate,” “believe,” “estimate,” “project,” “intend,” “goal,” “objective,” “predict,” “potential” or “continue,” or the negative of these terms and other comparable terminology. These forward-looking statements, which are based on various underlying assumptions and expectations and are subject to risks, uncertainties and other unknown factors, may include projections of our future financial performance based on our growth strategies and anticipated trends in our industry and our business. These statements are only predictions based on our current expectations and projections about future events that we believe to be reasonable. There are important factors that could cause our actual results, level of activity, performance or achievements to differ materially from the historical or future results, level of activity, performance or achievements expressed or implied by such forward-looking statements. These factors include, but are not limited to, those discussed under the caption “Risk Factors” in this report and in our 2014 10-K. In preparing this MD&A, we presume that readers have access to and have read the MD&A in our 2014 10-K pursuant to Instruction 2 to paragraph (b) of Item 303 of Regulation S-K. We undertake no duty to update any of these forward-looking statements after the date we file this report to conform such forward-looking statements to actual results or revised expectations, except as otherwise required by law.

Overview

We are the leading provider of natural gas as an alternative fuel for vehicle fleets in the United States and Canada, based on the number of stations operated and the amount of gasoline gallon equivalents (“GGEs”) of compressed natural gas (“CNG”) and liquefied natural gas (“LNG”) delivered. We design, build, operate and maintain fueling stations and supply our customers with CNG fuel for light, medium and heavy-duty vehicles and LNG fuel for medium and heavy-duty vehicles. We also manufacture, sell and service non-lubricated natural gas fueling compressors and other equipment used in CNG stations and LNG stations, provide operation and maintenance (“O&M”) services to customers, offer assessment, design and modification solutions to provide operators with code-compliant service and maintenance facilities for natural gas vehicle fleets, transport and sell CNG to large industrial and institutional energy users who do not have direct access to natural gas pipelines, process and sell renewable natural gas (“RNG”), which can be used as vehicle fuel or sold for renewable power generation, sell tradable credits we generate by selling natural gas and RNG as a vehicle fuel, including credits we generate under the California Low Carbon Fuel Standard (“LCFS Credits”) and Renewable Identification Numbers (“RIN Credits” or “RINs”) we generate under the federal Renewable Fuel Standard Phase 2, help our customers acquire and finance natural gas vehicles and obtain local, state and federal grants and incentives.

We sell natural gas vehicle fuels in the forms of CNG, LNG and RNG. CNG is produced from natural gas that is supplied by local utilities and third-party marketers to CNG vehicle fueling stations, where it is compressed and dispensed into vehicles in gaseous form. We also provide CNG via trailers in its compressed form directly from the fueling station and by delivering and vaporizing LNG to turn liquefied natural gas into compressed natural gas. LNG is natural gas that is cooled at a liquefaction facility to approximately —260 degrees Fahrenheit until it condenses into a liquid, which takes up about 1/600th of its original volume as a gas. We deliver LNG to fueling stations via our fleet of 84 tanker trailers. At the stations, LNG is stored in above-ground tanks until dispensed into vehicles in liquid form. RNG is produced from waste streams such as landfills, animal waste digesters and waste water treatment plants. RNG production plants are connected to natural gas pipelines, which allow RNG to be transported to vehicle fueling stations, where it can be compressed and dispensed as CNG, and to LNG liquefaction facilities, where it is converted to LNG.

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We serve fleet vehicle operators in a variety of markets, including heavy-duty trucks, airports, taxis, refuse, fleet services, ready mix and public transit. We believe these fleet markets will continue to present a high growth opportunity for natural gas vehicle fuels for the foreseeable future. At June 30, 2015, we served approximately 921 fleet customers operating approximately 41,851 natural gas vehicles, and we owned, operated or supplied 566 natural gas fueling stations in 42 states and in British Columbia and Ontario within Canada.

We believe we are positioned to capture a substantial share of the anticipated future growth in the use of natural gas as a vehicle fuel in the U.S. given our leading market share and the comprehensive solutions we offer.

Sources of Revenue.

We generate revenues by selling CNG and LNG, providing O&M services to our vehicle fleet customers, designing and constructing fueling stations and selling those stations to our customers, processing and selling RNG, manufacturing, selling and servicing non-lubricated natural gas fueling compressors and other equipment for CNG and LNG fueling stations, providing maintenance services, offering assessment, design and modification solutions to provide operators with code-compliant service and maintenance facilities for natural gas vehicle fleets, transporting and selling CNG to large industrial and institutional energy users who do not have direct access to natural gas pipelines, providing financing for our customers’ natural gas vehicle purchases, selling tradable LCFS Credits and RIN Credits, and receiving federal fuel tax credits.

Key Operating Data.

In evaluating our operating performance, our management focuses primarily on: (1) the amount of CNG and LNG gasoline gallon equivalents delivered (which we define as (i) the volume of gasoline gallon equivalents we sell to our customers, plus (ii) the volume of gasoline gallon equivalents dispensed at facilities where we provide O&M services, but do not sell the CNG or LNG, plus (iii) our proportionate share of the gasoline gallon equivalents sold as CNG by our joint venture with Mansfield Ventures, LLC called Mansfield Clean Energy Partners, LLC (“MCEP”), plus (iv) our proportionate share (as applicable) of the gasoline gallon equivalents of RNG produced and sold as pipeline quality natural gas by the RNG production facilities we own or operate), (2) our gross margin (which we define as revenue minus cost of sales), and (3) net loss attributable to us. The following table, which you should read in conjunction with our condensed consolidated financial statements and notes included in this report and our consolidated financial statements and notes contained in our 2014 10-K, presents our key operating data for the years ended December 31, 2012, 2013, and 2014 and for the three and six months ended June 30, 2014 and 2015:

Gasoline gallon equivalents delivered (in millions)	Year Ended December 31, 2012	Year Ended December 31, 2013	Year Ended December 31, 2014	Three Months Ended June 30, 2014	Three Months Ended June 30, 2015	Six Months Ended June 30, 2014	Six Months Ended June 30, 2015
CNG	130.5	143.9	182.6	43.5	54.9	82.9	107.3
RNG	8.9	10.5	12.2	3.0	1.9	6.2	6.4
LNG	55.5	60.0	70.3	18.3	17.6	35.0	35.9
Total	194.9	214.4	265.1	64.8	74.4	124.1	149.6

Operating data
Gross margin	$	80,324		$	127,713	(1)	$	120,153	(1)	$	24,878		$	23,082		$	48,522		$	44,197
Net loss attributable to Clean Energy Fuels. Corp	(101,255		)	(66,968		)(1)	(89,659		)(1)	(32,306		)	(29,962		)	(60,899		)	(61,109		)

(1) Includes $45.4 million and $28.4 million of revenue for the years ended December 31, 2013 and 2014, respectively, from VETC of $0.50 per gasoline gallon equivalent of CNG and $0.50 per liquid gallon of LNG that we sold as vehicle fuel. See discussion under “Operations — VETC” below.

Key Trends.

CNG and LNG are generally cheaper on an energy equivalent basis and, according to studies conducted by the California Air Resources Board and Argonne National Laboratory, a research laboratory operated by the University of Chicago for the United States Department of Energy, cleaner than gasoline and diesel fuel. According to the U.S. Department of Energy’s Energy Information Administration (“EIA”), the amount of natural gas consumed in the U.S. for vehicle use more than doubled between 2000 and 2014 and demand for natural gas fuels in the United States increased by approximately 52% during the period January 1, 2011 through December 31, 2014. We believe this growth in consumption and demand was attributable primarily to the higher prices of gasoline and diesel relative to CNG and LNG during much of these periods, increasingly stringent environmental regulations affecting vehicle fleets, which have driven the need for cleaner vehicle fuels, and increased availability of natural gas.

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The number of fueling stations we owned, operated, maintained and/or supplied grew from 273 at January 1, 2012 to 566 at June 30, 2015 (a 107.3% increase). Included in this number are all of the CNG and LNG fueling stations we own, maintain or with which we have a fueling supply contract. The amount of CNG, RNG, and LNG gasoline gallon equivalents we delivered from 2012 to 2014 increased by 36.0%. The increase in gasoline gallon equivalents delivered was the primary contributor to increased revenues during 2012, 2013 and 2014. In addition, in 2013 and 2014, revenues included federal fuel tax credit (“VETC”) revenues of $45.4 million and $28.4 million, respectively, with the 2013 VETC revenues including $20.8 million related to 2012 due to the reinstatement of VETC in January 2013. We have not recognized any VETC revenue during the six months ended June 30, 2015, as the program providing for the credit expired December 31, 2014 and has not been reinstated. Our revenue can vary between periods for various reasons, including the timing of equipment sales, station construction, recognition of VETC and other credits, and natural gas sale activity.

Our fuel cost of sales also increased from 2012 through 2014, which was attributable primarily to increased costs related to delivering more CNG, RNG and LNG to our customers during this period. Our cost of sales can vary between periods for various reasons, including the timing of equipment sales, station construction and natural gas sale activity.

In the recent past, the prices of oil, gasoline, diesel and natural gas have been volatile and generally decreased, and this environment of volatility and decreasing prices may continue. These conditions have resulted in lower revenues from reduced prices we charge for CNG and LNG and, to a lesser degree lower profit margin, as a result of lower natural gas commodity costs. Further, the global decline in oil prices, the strength of the U.S. dollar, and slower than expected sales in China has resulted in weaker than expected demand in non-U.S. markets for the natural gas fueling compressors and other equipment manufactured and sold by our Clean Energy Compression (formerly IMW Industries) subsidiary. To the extent these volatile and lower-cost conditions persist, our financial results may continue to be adversely affected.

Recent Developments

On July 31, 2015, President Obama signed into law a comprehensive highway funding bill that includes a measure to equalize the federal tax on LNG to an energy-equivalent basis with diesel. We are evaluating the financial impact of the measure, which is effective January 1, 2016.

Anticipated Future Trends.

We anticipate that, over the long term, the prices for gasoline and diesel will continue to be higher than the price of natural gas as a vehicle fuel, which will continue to make natural gas vehicle fuel an attractive alternative to gasoline and diesel. Our belief that natural gas will continue, over the long term, to be a cheaper vehicle fuel than gasoline or diesel is based in large part on the growth in United States natural gas production in recent years.

We believe CNG and LNG are well-suited for use by vehicle fleets that consume high volumes of fuel, refuel at centralized locations or along well defined routes, and are increasingly required to reduce emissions. As a result, we believe there will be significant growth in the consumption of natural gas as a vehicle fuel among vehicle fleets, and our goal is to capitalize on this trend if and to the extent it materializes and enhance our leadership position if and as the market expands. We anticipate expanding our sales of CNG, RNG and LNG in each of the markets in which we operate, including heavy-duty trucking, refuse, airports, ready mix, fleet services, taxis and public transit, and plan to enter additional markets, including potentially rail. Consistent with the anticipated growth of our business, we also expect that our operating costs and capital expenditures will increase, primarily from the anticipated expansion of our station network and LNG and RNG production capacity, as well as the logistics of delivering more CNG, LNG and RNG to our customers. We also anticipate that we will continue to seek to acquire assets and/or businesses that are in the natural gas fueling infrastructure or RNG production business that may require us to raise and expend additional capital. Additionally, we have increased, and will continue to increase, our personnel as we seek to expand our existing markets and enter new markets, which will also result in increased costs.

We expect competition to intensify in the near term in the market for natural gas vehicle fuel. Increased competition will lead to amplified pricing pressure and reduced operating margins.

Sources of Liquidity and Anticipated Uses of Cash

Liquidity is the ability to meet present and future financial obligations through operating cash flows, the sale or maturity of existing assets, or the acquisition of additional funds through capital management. Historically, our principal sources of liquidity have consisted of cash on hand, cash provided by financing activities and, if available, VETC and other credits.

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LNG supply, or use capital for other activities or pursuits. We will need to raise additional capital as necessary to fund any capital expenditures, investments or debt repayments that we cannot fund through available cash or cash generated by operations or that we cannot fund through other sources, such as with our common stock. The timing and necessity of any future capital raise would depend on various factors, including our rate of new station construction, any potential merger or acquisition activity, and other factors. 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 capital may impair our ability to build new stations, develop natural gas fueling infrastructure, invest in strategic transactions or acquisitions or repay our outstanding indebtedness and may reduce our ability to grow our business and generate sustained or increased revenues.

Business Risks and Uncertainties

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.

Operations

We generate revenues principally by selling CNG, LNG and RNG and providing O&M services to our vehicle fleet customer stations. For the six months ended June 30, 2015, CNG and RNG (together) represented 76% and LNG represented 24% of our natural gas sales (on a gasoline gallon equivalent basis). To a lesser extent, we generate revenues by designing and constructing fueling stations and selling or leasing those stations to our customers.

We also generate revenues through sales of non-lubricated natural gas fueling compressors and other equipment for CNG and LNG stations, providing maintenance services, offering assessment, design and modification solutions to provide vehicle fleet operators with code- compliant service and maintenance facilities for natural gas vehicle fleets, transporting and selling CNG to large industrial and institutional energy users who do not have direct access to natural gas pipelines, providing financing for our customers’ natural gas vehicle purchases, selling tradable RINs and LCFS Credits, and receiving federal fuel tax credits.

CNG Sales

We sell CNG through fueling stations and by transporting it to customers without direct access to a natural gas pipeline. CNG fueling station sales are made through stations located on our customers’ properties and through our network of public access fueling stations. At these CNG fueling stations, we procure natural gas from local utilities or third-party marketers and then compress and dispense it into our customers’ vehicles. Our CNG fueling station sales are made primarily through contracts with our customers. Under these contracts, pricing is principally determined on an index-plus basis, which is calculated by adding a margin to the local index or utility price for natural gas. CNG sales revenues based on an index-plus methodology increase or decrease as a result of an increase or decrease in the price of natural gas. Our customers typically are billed monthly based on the volume of CNG sold at a station. The remainder of our CNG fueling station sales are on a per fill-up basis at prices we set at public access stations based on prevailing market conditions.

Additionally, our subsidiary, NG Advantage, LLC (“NG Advantage”), uses a fleet of 54 high-capacity tube trailers to deliver CNG to large institutions and industrial energy users, such as hospitals, food processors, manufacturers and paper mills that do not have direct access to natural gas pipelines. Utilizing its trailer fleet, NG Advantage creates a “virtual natural gas pipeline” that allows large oil, diesel or propane users to take advantage of the cost savings and environmental benefits of natural gas. We anticipate that NG Advantage will need to purchase or lease additional trailers to transport CNG in support of its operations.

LNG Production and Sales

We obtain LNG from our own plants as well as through relationships with suppliers. We own and operate LNG liquefaction plants near Houston, Texas and Boron, California. We may expand the production capacity of the Boron, California plant, and we have obtained a commitment from General Electric Capital Corporation (“GE”) to, subject to our satisfaction of certain conditions, partially finance our purchase of two new LNG plants to be built by an affiliate of GE (see note 12 to our condensed consolidated financial statements).

We sell LNG on a bulk basis to fleet customers, who often own and operate their fueling stations, and we also sell LNG to fleet and other customers at our public-access LNG stations. Further, we sell LNG for non-vehicle purposes, including to customers who use LNG in the oil fields or for industrial applications or utility applications. During 2014 and through June 30, 2015, we procured 44% and 43%, respectively, of our LNG from third-party producers, and we produced the remainder of our LNG at our liquefaction plants in Texas and California. For certain LNG that we purchase from third parties, we have entered into “take or pay” contracts that require us to purchase minimum volumes of LNG at index-based rates. We expect to enter additional purchase contracts

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with third-party LNG producers in the future to support our LNG supply needs, some of which may be “take or pay” contracts. We deliver LNG via our fleet of 84 tanker trailers to fueling stations, where it is stored and dispensed in liquid form into vehicles. We anticipate that we will need to purchase or lease additional tanker trailers to transport LNG, and that we will need to increase the number of third parties who provide us contract carrier services. We sell LNG through supply contracts that are priced on an index-plus basis. LNG sales revenues based on an index-plus methodology increase or decrease as a result of an increase or decrease in the price of natural gas. We also sell LNG on a per fill-up basis at prices we set at public access stations based on prevailing market conditions. LNG generally costs more than CNG, as LNG must be liquefied and transported, and the U.S. government imposes higher fuel taxes on LNG.

VETC

From October 1, 2006 through December 31, 2014, we were eligible to receive a VETC of $0.50 per gasoline gallon equivalent of CNG and $0.50 per liquid gallon of LNG that we sold as vehicle fuel. Based on the service relationship with our customers, either we or our customers claimed the credit. We recorded these tax credits as revenues in our consolidated statements of operations, as the credits are fully refundable and do not need to offset tax liabilities to be received. As such, the credits are not deemed income tax credits under the accounting guidance applicable to income taxes. In addition, we believe the credits are properly recorded as revenue because we often incorporate the tax credits into our pricing with our customers, thereby lowering the actual price per gallon we charge them.

Our VETC revenue for calendar year 2014 was all recognized in December 2014 and no VETC revenues have been recognized during 2015, as the program under which we received the credit expired December 31, 2014 and has not been reinstated.

Operation and Maintenance

We generate a portion of our revenue from our performance of O&M services for CNG and LNG fueling stations. For these services we generally charge a per-gallon fee based on the volume of fuel dispensed at the station. We include the volume of fuel dispensed at the stations at which we provide O&M services in our calculation of aggregate gasoline gallon equivalents delivered.

Station Construction and Engineering

We generate a portion of our revenue from designing and constructing fueling stations and selling or leasing some of the stations to our customers. For these projects, we typically act as general contractor or supervise qualified third-party contractors. We also offer assessment, design and modification solutions to provide vehicle fleet operators with code-compliant service and maintenance facilities for natural gas vehicle fleets, which can include the construction and sale of facility modifications, including our NGV Easy Bay™ product, a natural gas vapor leak barrier developed specifically for natural gas vehicle facilities. We charge construction or other fees or lease rates based on the size and complexity of the project.

RNG

We own an RNG production facility located at a Republic Services landfill in Canton, Michigan. This facility was completed in 2012, and we have entered into a ten-year fixed-price sale contract for the majority of the RNG that we expect the facility to produce. We built another RNG production facility at a Republic Services landfill in North Shelby, Tennessee. We are seeking to expand our RNG business by pursuing additional RNG production projects, either on our own or with project partners. We sell some of the RNG we produce, and expect to sell a significant amount of the RNG we produce at the facilities we plan to build, through our natural gas fueling infrastructure for use as a vehicle fuel. In addition, we purchase RNG from third-party producers, and sell that RNG for vehicle fuel use through our fueling infrastructure. The RNG we sell for vehicle fuel use is distributed under the name Redeem™. On December 29, 2014, we sold our full ownership interest in our former subsidiary, Dallas Clean Energy, LLC (“DCE”), together with its subsidiary Dallas Clean Energy McCommas Bluff, LLC (“DCEMB”), for approximately $40.6 million and may receive up to an additional $1.3 million in cash, subject to the results of certain performance tests to be performed at the RNG extraction and production project owned by DCEMB. For the six months ended June 30, 2014, DCE contributed approximately $8.4 million to our revenue. We continued to perform O&M services for DCEMB subsequent to the sale and recognized $0.4 million in revenue for such services during the six months ended June 30, 2015.

Natural Gas Fueling Compressors

Our subsidiary, Clean Energy Compression, formerly known as IMW, manufactures, sells and services non-lubricated natural gas fueling compressors and related equipment for the global natural gas fueling market. Clean Energy Compression is headquartered near Vancouver, British Columbia, has an additional manufacturing facility near Shanghai, China and has sales and service offices in Bangladesh, Colombia, Peru and the U.S. For the six months ended June 30, 2014 and 2015, Clean Energy Compression contributed approximately $44.0 million and $28.5 million, respectively, to our revenue.

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Sales of RINs and LCFS Credits

We generate LCFS Credits when we sell RNG and conventional natural gas for use as a vehicle fuel in California, and we generate RIN Credits when we sell RNG for use as a vehicle fuel. We can sell these credits to third parties who need the RINs and LCFS Credits to comply with federal and state requirements. During the first six months of 2014, we realized $0.8 million and $1.9 million in revenue through the sale of RIN Credits and LCFS Credits, respectively. During the six months ended June 30, 2015, we realized $5.3 million and $2.1 million in revenue through the sale of RIN Credits and LCFS Credits, respectively. We anticipate that we will generate and sell increasing numbers of RINs and LCFS Credits as we sell increasing amounts of CNG, LNG and RNG for use as a vehicle fuel. The market for RINs and LCFS Credits is volatile, and the prices for such credits may be subject to significant fluctuations. Further, the value of RINs and LCFS Credits will be adversely affected by any changes to the state and federal programs under which such credits are generated and sold.

Vehicle Acquisition and Finance

We offer vehicle finance services, including loans and leases, to help our customers acquire natural gas vehicles. Where appropriate, we apply for and receive state and federal incentives associated with natural gas vehicle purchases and pass these benefits through to our customers. We may also secure vehicles to place with customers or pay deposits with respect to such vehicles prior to receiving a firm order from our customers, which we may be required to purchase if our customer fails to purchase the vehicle as anticipated. Through June 30, 2015, we have not generated significant revenue from vehicle financing activities.

Volatility of Earnings Related to Series I Warrants

Under Financial Accounting Standards Board (“FASB”) authoritative guidance, we are required to record the change in the fair market value of our Series I warrants in our consolidated financial statements. We have recognized a gain of $2.2 million and $0.6 million, respectively, related to recording the estimated fair value changes of our Series I warrants in the six months ended June 30, 2014 and 2015. See note 17 to our condensed consolidated financial statements included in this report. Our earnings or loss per share may be materially affected by future gains or losses we are required to recognize as a result of valuing our Series I warrants. As of June 30, 2015, 2,130,682 of the Series I warrants remained outstanding.

Debt Compliance

The loan agreements relating to the 7.5% Notes, as defined and discussed in note 12 to our condensed consolidated financial statements, have certain non-financial debt covenants with which we must comply. As of June 30, 2015, we were in compliance with these covenants.

The convertible note purchase agreements relating to the SLG Notes, as defined and discussed in note 12 to our condensed consolidated financial statements, have certain non-financial debt covenants with which we must comply. As of June 30, 2015, we were in compliance with these covenants.

The Credit Agreement, as defined below and as discussed in note 12 to our condensed consolidated financial statements, contains certain covenants with which we must comply. As of June 30, 2015, we were in compliance with these covenants.

The indenture relating to the 5.25% Notes, as defined and discussed in note 12 to our condensed consolidated financial statements, has certain non-financial debt covenants with which we must comply. As of June 30, 2015, we were in compliance with these covenants.

The Bonds, as defined below and as discussed in note 12 to our condensed consolidated financial statements, contain certain debt covenants with which we must comply. As of June 30, 2015, we were in compliance with these covenants.

Risk Management Activities

Our risk management activities are discussed in Part II, Item 7 (Management’s Discussion and Analysis of Financial Condition and Results of Operations) of our 2014 10-K. For the quarter ended June 30, 2015, there were no material changes to our risk management activities.

Critical Accounting Policies

Our critical accounting policies are discussed in Part II, Item 7 (Management’s Discussion and Analysis of Financial Condition and Results of Operations) of our 2014 10-K. For the quarter ended June 30, 2015, there were no material changes to such critical accounting policies.

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Recently Adopted Accounting Changes and Recently Issued Accounting Standards

For a description of recently adopted accounting changes and recently issued accounting standards, see note 18 to our condensed consolidated financial statements included in this report.

Results of Operations

The following is a detailed discussion of our results of operations for the periods presented:

	Three Months Ended June 30,				Six Months Ended June 30,
	2014		2015		2014		2015
Statement of Operations Data:
Revenue:
Product revenues	88.1	%	87.2	%	89.1	%	84.0	%
Service revenues	11.9		12.8		10.9		16.0
Total revenues	100.0		100.0		100.0		100.0
Operating expenses:
Cost of sales:
Product cost of sales	70.5		68.4		70.9		66.4
Service cost of sales	4.2		5.1		4.1		8.0
Derivative (gains) losses on Series I warrant valuation	2.3		0.3		(1.1	)	(0.3	)
Selling, general and administrative	35.1		33.4		35.1		34.3
Depreciation and amortization	11.8		15.4		12.0		15.2
Total operating expenses	123.9		122.6		121.0		123.6
Operating loss	(23.9	)	(22.6	)	(21.0	)	(23.6	)
Interest expense, net	(10.3	)	(11.5	)	(10.2	)	(11.5	)
Other income (expense), net	1.1		0.4		(0.1	)	0.5
Loss from equity method investment	—		(0.4	)	—		(0.3	)
Loss before income taxes	(33.1	)	(34.1	)	(31.3	)	(34.9	)
Income tax expense	(0.1	)	(0.9	)	(0.6	)	(0.9	)
Net loss	(33.2	)	(35.0	)	(31.9	)	(35.8	)
Loss of noncontrolling interest	0.3		0.5		0.2		0.4
Net loss attributable to Clean Energy Fuels Corp.	(32.9	)	(34.5	)	(31.7	)	(35.4	)

Three Months Ended June 30, 2014 Compared to Three Months Ended June 30, 2015

Revenue. Revenue decreased by $11.2 million to $86.9 million in the three months ended June 30, 2015, from $98.1 million in the three months ended June, 30 2014. Fewer station construction sales in the three months ended June 30, 2015 led to a decrease of $5.2 million in revenue between periods, from $14.7 million in revenue attributable to station construction sales in the three months ended June 30, 2014, to $9.5 million in revenue attributable to station construction sales in the same period in 2015. We also experienced a decrease of $8.1 million in revenue related to Clean Energy Compression between periods, to $21.8 million in revenue in the three months ended June 30, 2014, compared to $13.7 million in revenue attributable to such sales in the same period in 2015 due to the effects of the global decline in oil prices, the strength of the U.S. dollar, and slower than expected sales in China. Approximately $5.6 million of the decrease in revenue was the result of lower fuel prices which were driven by lower commodity costs in 2015 compared to 2014. Incremental volumes in the second quarter of 2015 over volumes in the same period in 2014 resulted in approximately $7.9 million in incremental revenue in the second quarter of 2015 compared to the same period in 2014. Our effective price per gallon charged was $0.83 in the three months ended June 30, 2015, which represents a $0.10 per gallon decrease from $0.93 per gallon charged in the three months ended June 30, 2014. The effective price decrease was primarily due to lower fuel prices driven by lower commodity costs. The number of gallons delivered between periods increased 9.6 million gallons from 64.8 million gasoline gallon equivalents to 74.4 million gasoline gallon equivalents. The increase in volume was primarily from an increase of 11.4 million gallons of CNG. Our net increase in CNG volume was primarily from 18 new refuse customers, five new transit customers, two new industrial customers, and three new trucking customers, which together accounted for 8.2 million gallons of CNG volume increase. We also experienced a decrease of 1.1 million gallons in our RNG sales, primarily due to the sale, effective December 29, 2014, of our interest in a renewable natural gas extraction and processing project at the McCommas Bluff landfill in Dallas, Texas. LNG volume declined 0.7 million gallons between periods from our industrial, refuse and trucking customers primarily due to timing of contract renewals.

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Cost of sales. Cost of sales decreased by $9.5 million to $63.8 million in the three months ended June 30, 2015, from $73.3 million in the three months ended June 30, 2014. The decrease was primarily due to fewer station sales to customers and a decrease in gas commodity costs. We experienced a $4.5 million decrease in station installation costs between periods. Our effective cost per gallon decreased by $0.08 per gallon, from $0.64 per gallon in the three months ended June 30, 2014 to $0.56 per gallon in the three months ended June 30, 2015. This decrease was primarily due to lower gasoline, diesel and natural gas prices. The decrease in natural gas prices largely negated the impact on cost of gas sold of increased volumes resulting in a net decrease of $0.8 million in gas commodity costs. Furthermore, fewer compressor sales from Clean Energy Compression led to a decrease in costs of $5.5 million.

Derivative (gain) loss on Series I warrant valuation. Derivative loss decreased by $2.0 million to $0.3 million in the three months ended June 30, 2015, from $2.3 million in the three months ended June 30, 2014. The amounts represent the non-cash impact with respect to valuing our outstanding Series I warrants based on our mark-to-market accounting for the warrants during the periods (see note 17 to our condensed consolidated financial statements contained elsewhere in this report).

Selling, general and administrative. Selling, general and administrative expenses decreased by $5.4 million to $29.0 million in the three months ended June 30, 2015, from $34.4 million in the three months ended June 30, 2014. This decrease was primarily driven by a $1.6 million decrease in salaries and employee benefits and fewer station related costs of $0.6 million compared to the prior period. Travel and entertainment expenses and consulting fees decreased in total by $0.7 million due to company-wide cost cutting measures. Furthermore, research and development costs and business insurance expenses decreased $0.4 million and $0.5 million, respectively due to a reduction in CE compressor project costs and general liability insurance.

Depreciation and amortization. Depreciation and amortization increased by $1.8 million to $13.4 million in the three months ended June 30, 2015, from $11.6 million in the three months ended June 30, 2014. This increase was primarily due to additional depreciation expense in the three months ended June 30, 2015 related to increased property and equipment balances between periods, primarily related to our expanded station network and the property, plant and equipment and intangible assets we acquired in our acquisition of NG Advantage during the fourth quarter of 2014.

Interest expense, net. Interest expense, net, decreased by $0.1 million to $10.0 million for the three months ended June 30, 2015, from $10.1 million for the three months ended June 30, 2014. This decrease was primarily due to the payment of DCEMB debt as a result of its sale, offset by an increase in interest expense related to NG Advantage debt.

Other income (expense), net. Other income (expense), net, decreased by $0.8 million to $0.3 million of income for the three months ended June 30, 2015, compared to $1.1 million of income for the three months ended June 30, 2014. This decrease was primarily due to a $0.4 million foreign currency exchange rate change between periods related to Clean Energy Compression.

Loss from equity method investment. During the three months ended June 30, 2015, we recorded $0.3 million loss in our Mansfield Clean Energy Partners LLC (“MCEP”) joint venture.

Income tax expense. Income tax expense increased by $0.6 million to $0.7 million for the three months ended June 30, 2015, compared to $0.1 million for the three months ended June 30, 2014. The increase is primarily attributable to an increase in taxes on foreign operations between periods.

Loss from noncontrolling interest. During the three months ended June 30, 2015 we recorded a loss of $0.4 million for the noncontrolling interest in the net loss of NG Advantage, compared to $0.3 million recorded for the noncontrolling interest in the net loss of our former subsidiary DCEMB in the three months ended June 30, 2014. The noncontrolling interest in DCEMB and NG Advantage represented the 30% and 46.7% minority interest in these entities, respectively, which were held by third parties during the applicable periods.

Six Months Ended June 30, 2014 Compared to Six Months Ended June 30, 2015

Revenue. Revenue decreased by $20.7 million to $172.7 million in the six months ended June 30, 2015, from $193.4 million in the six months ended June 30, 2014. Fewer station construction sales in the six months ended June 30, 2015 led to a decrease of $15.0 million in revenue between periods, from $31.0 million in revenue attributable to station construction sales in the six months ended June 30, 2014, compared to $16.0 million in revenue attributable to station construction sales in the same period in 2015. We also experienced a decrease of $15.6 million in revenue related to Clean Energy Compression between periods, from $44.1 million in revenue in the six months ended June 30, 2014, to $28.5 million in revenue attributable to such sales in the same period in 2015 due to the global decline in oil prices, the strength of the U.S. dollar, and slower than expected sales in China. Approximately $9.9 million of the decrease was the result of lower fuel prices which were driven by lower commodity costs in 2015 compared to 2014. Incremental volumes in the six months ended June 30, 2015 over volumes in the same period in 2014 resulted in approximately $21.4 million in incremental

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revenue in the first half of 2015 compared to the same period in 2014. Our effective price per gallon charged was $0.84 in the six months ended June 30, 2015, which represents a $0.10 per gallon decrease from $0.94 per gallon charged in the six months ended June 30, 2014. The effective price decrease was primarily due to lower fuel prices driven by lower commodity costs. . The number of gallons delivered between periods increased from 124.1 million gasoline gallon equivalents to 149.6 million gasoline gallon equivalents. The increase in volume was primarily from an increase of 24.4 million gallons of CNG. Our net increase in CNG volume was primarily from 20 new refuse customers, seven new transit customers, two new industrial customers, and five new trucking customers, which together accounted for 15.8 million gallons of CNG volume increase. We also experienced a 0.2 million gallons increase in our RNG sales, primarily due to increased RNG production at our Shelby, Tennessee facility. LNG volume increased 0.9 million gallons between periods from our industrial, refuse and trucking customers primarily due to the addition of new customers.

Cost of sales. Cost of sales decreased by $16.4 million to $128.5 million in the six months ended June 30, 2015, from $144.9 million in the six months ended June 30, 2014. The decrease was primarily due to fewer stations sales, as we experienced a $12.3 million decrease in station construction costs between periods due to decreased activity. Our effective cost per gallon decreased by $0.09 per gallon, from $0.66 per gallon in the six months ended June 30, 2014 to $0.57 per gallon in the six months ended June 30, 2015. This decrease was primarily due to lower gasoline, diesel and natural gas prices. The decrease in natural gas prices largely negated the impact of increased volume resulting in $4.0 million in increased gas commodity costs. Cost of sales that Clean Energy Compression incurred decreased between periods by $8.2 million due to its decreased sales between periods.

Derivative (gain) loss on Series I warrant valuation. Derivative gain decreased by $1.6 million to a gain of $0.6 million in the six months ended June 30, 2015, from a $2.2 million gain in the six months ended June 30, 2014. The amounts represent the non-cash impact with respect to valuing our outstanding Series I warrants based on our mark-to-market accounting for the warrants during the periods. (See note 17 to our condensed consolidated financial statements contained elsewhere herein).

Selling, general and administrative. Selling, general and administrative expenses decreased by $8.7 million to $59.2 million in the six months ended June 30, 2015, from $67.9 million in the six months ended June 30, 2014. This decrease was driven by $6.8 million in decreases in salaries and employee expenses, stock based compensation expense, travel and entertainment expenses, restructuring costs, and consulting services between periods due to company-wide cost cutting measures. We also experienced a $1.4 million decrease in business insurance and research and development costs.

Depreciation and amortization. Depreciation and amortization increased by $3.2 million to $26.3 million in the six months ended June 30, 2015, from $23.1 million in the six months ended June 30, 2014. This increase was primarily due to additional depreciation expense in the six months ended June 30, 2015 related to increased property and equipment balances between periods, primarily related to our expanded station network and property, plant and equipment and intangible assets we acquired in our acquisition of NG Advantage during the fourth quarter of 2014.

Interest expense, net. Interest expense, net, increased by $0.3 million to $19.9 million for the six months ended June 30, 2015, from $19.6 million for the six months ended June 30, 2014. This increase was primarily due to interest expense relating to NG Advantage debt, offset by the payment of DCEMB debt as a result of its sale at December 29, 2014.

Other income (expense), net. Other income (expense), net, increased by $1.1 million to an income of $0.9 million for the six months ended June 30, 2015, compared to expense of $0.2 million for the six months ended June 30, 2014. This decrease was primarily due to $0.8 million of foreign currency exchange rate change between periods related to Clean Energy Compression.

Loss from equity method investment. During the six months ended June 30, 2015, we recorded $0.5 million loss in our Mansfield Clean Energy Partners LLC (“MCEP”) joint venture.

Income tax expense. Income tax expense increased by $0.5 million to $1.6 million for the six months ended June 30, 2015, compared to $1.1 million for the six months ended June 30, 2014. The increase is primarily attributable to an increase in taxes on foreign operations between periods.

Loss of noncontrolling interest. During the six months ended June 30, 2015, we recorded $0.8 million for the noncontrolling interest in the net loss of NG Advantage. In the prior comparable period, we recorded $0.3 million for the noncontrolling interest in the net loss of DCEMB. The noncontrolling interest in DCEMB and NG Advantage represented the 30% and 46.7% minority interest in these entities, respectively, which were held by third parties during the applicable periods.

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Seasonality and Inflation

To some extent, we experience seasonality in our results of operations. Natural gas vehicle fuel amounts consumed by some of our customers tend to be higher in summer months when buses and other fleet vehicles use more fuel to power their air conditioning systems. Natural gas commodity prices tend to be higher in the fall and winter months due to increased overall demand for natural gas for heating during these periods.

Since our inception, inflation has not significantly affected our operating results. However, costs for construction, repairs, maintenance, electricity and insurance are all subject to inflationary pressures, which could affect our ability to maintain our stations adequately, build new stations, build new LNG plants or expand our existing facilities, or could materially increase our operating costs.

Liquidity and Capital Resources

We require cash to fund our capital expenditures, operating expenses and working capital requirements, including outlays for the design and construction of new fueling stations, the construction, expansion and maintenance of LNG production facilities, the purchase of new CNG tanker trailers, investment in RNG production, the manufacturing of natural gas fueling compressors and other equipment, mergers and acquisitions, the financing of natural gas vehicles for our customers and general corporate purposes, including making deposits to support our derivative activities, geographic expansion (domestically and internationally), expanding our sales and marketing activities, support of legislative and regulatory initiatives and for working capital. Historically, our principal sources of liquidity have consisted of cash on hand, cash provided by financing activities and, if available, VETC and other credits.

Liquidity

Cash used in operating activities was $2.9 million for the six months ended June 30, 2015, compared to $43.3 million for the six months ended June 30, 2014. Operating cash flows increased between periods primarily due to a $47.8 million increase in net collections of accounts and other receivables in the six months ended June 30, 2015, compared to the same period in 2014. The majority of the increased collections in the first six months of 2015 related to the cash receipt of $28.4 million of VETC revenues attributable to natural gas vehicle fuel sales in 2014. Accrued expenses and other decreased $16.4 million from June 30, 2014 to June 30, 2015 due to timing of customer reimbursements and recognition of deferred revenue. We also experienced other working capital changes between periods due to timing differences.

Cash used in investing activities was $33.2 million for the six months ended June 30, 2015, compared to $81.5 million for the six months ended June 30, 2014. We purchased property and equipment for $26.2 million in the six months ended June 30, 2015, which is a decrease of $35.6 million from $61.8 million paid to purchase property and equipment in the six months ended June 30, 2014. This decrease is primarily related to capital expenditures for CNG and LNG station equipment, which includes $18.4 million for the purchase of 67 CNG-In-A-Box units, which consist of relatively small, turnkey, self-contained CNG stations, from Peake Fuel Solutions, LLC during the six months ended June 30, 2014, which were not repeated in the same period of 2015, and decreases in capital expenditures between periods related to station construction. Additionally, we had purchases of $6.8 million, net of maturities of short term investments, during the six months ended June 30, 2015, which is a decrease of $8.9 million from our $15.7 million of purchases, net of maturities of short term investments, in the six months ended June 30, 2014.

Cash used by financing activities for the six months ended June 30, 2015 was $1.9 million, compared to cash provided by financing of $9.1 million for the six months ended June 30, 2014. This decrease was primarily from the issuance of the bonds (the “Bonds”) by our subsidiary Canton Renewables, LLC (“Canton”) for $12.4 million, before issuance costs of $0.9 million, in the six months ended June 30, 2014, with no comparable issuance in the same period in 2015. The remaining decrease in funds provided by financing activities was caused by borrowings on a line of credit primarily to fund Clean Energy Compression’s working capital requirements that exceeded repayments in 2014 which did not repeat in 2015 as the line of credit was extinguished in the fourth quarter of 2014. Partially offsetting the excess borrowings over repayments on the line of credit in 2014 was larger repayments of capital leases and other debts in 2014 compared to 2015.

Our financial position and liquidity are, and will be, influenced by a variety of factors, including our ability to generate cash flows from operations, the level of our outstanding indebtedness and the principal and interest we are obligated to pay on our indebtedness, our capital expenditure requirements (which consist primarily of CNG and LNG fueling station construction costs, LNG plant construction, expansion and maintenance costs, RNG plant construction and maintenance costs and the purchase of LNG and CNG tanker trailers and equipment) and any merger or acquisition activity.

Sources of Cash

Historically, our principal sources of liquidity have consisted of cash on hand, cash provided by financing activities and, if available, grants, VETC and other credits. At June 30, 2015, we had total cash and cash equivalents and short-term investments of $181.9 million, compared to $214.9 million at December 31, 2014.

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On November 7, 2012, we, through two wholly owned subsidiaries (the “Borrowers”), entered into a credit agreement (the “Credit Agreement”) with GE. Pursuant to the Credit Agreement, GE agreed to loan to the Borrowers up to an aggregate of $200.0 million to finance the development, construction and operation of two LNG plants, subject to our satisfaction of certain conditions on or before December 31, 2014. In December 2014, we amended the Credit Agreement to, among other things, extend our ability to satisfy such conditions and draw the loans from December 31, 2014 to December 31, 2016.

On March 19, 2014, Canton completed the issuance of the Bonds in the aggregate principal amount of $12.4 million. The proceeds were used primarily to (i) refinance the cost of constructing and equipping its RNG extraction and production project in Canton, Michigan and (ii) pay a portion of the cost associated with the issuance of the Bonds.

See note 12 to our consolidated financial statements for a description of all of our outstanding long-term debt.

Capital Expenditures and Other Uses of Cash

Our business plan calls for approximately $33.8 million in capital expenditures from July 1, 2015 through the end of 2015, primarily related to construction of CNG and LNG fueling stations and the purchase of CNG trailers (these trailers are expected to be purchased by NG Advantage, and we anticipate that NG Advantage will use a portion of the purchase price we paid for our interest in that entity to fund such purchase). Additionally, we had total consolidated indebtedness of approximately $575.7 million as of June 30, 2015, of which approximately $3.4 million, $150.1 million, $5.5 million, $305.1 million, $54.6 million, $53.1 million, and $3.9 million will become due in 2015, 2016, 2017, 2018, 2019, 2020, and thereafter respectively. We may also elect to invest additional amounts in companies or assets in the natural gas fueling infrastructure, vehicle or services businesses, including RNG production, make capital expenditures to build additional or expand existing LNG production facilities or to otherwise secure future LNG supply, and use capital for other activities or pursuits. We will need to raise additional capital as necessary to fund any capital expenditures, investments or debt repayments that we cannot fund through available cash or cash generated by operations or that we cannot fund through other sources, such as with our common stock. The timing and necessity of any future capital raise would depend on various factors, including our rate of new station construction, any potential merger or acquisition activity, and other factors. We may seek to raise additional capital we need through one or more sources, including, among others, selling assets, obtaining new or restructuring existing debt, or obtaining equity capital, or any combination of these or other available 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 capital may impair our ability to build new stations, develop natural gas fueling infrastructure, invest in strategic transactions or acquisitions or repay our outstanding indebtedness and may reduce our ability of to grow our business and generate sustained or increased revenues.

Off-Balance Sheet Arrangements

At June 30, 2015, we had the following off-balance sheet arrangements that had, or are reasonably likely to have, a material effect on our financial condition:

· outstanding surety bonds for construction contracts and general corporate purposes totaling $44.3 million;

· one long-term take-or-pay contract for the purchase of LNG; and

· operating leases where we are the lessee.

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

We have one long-term take-or-pay contract that requires us to purchase minimum volumes of LNG at index based prices and expires in March 2020.

We have entered into operating lease arrangements for certain equipment and for our office and field operating locations in the ordinary course of business. The terms of our leases expire at various dates through 2021. Additionally, in November 2006, we entered into a ground lease for 36 acres in California on which we built our California LNG liquefaction plant. The lease is for an initial term of thirty years and requires payments of $0.2 million per year, plus up to $0.1 million per year for each 30 million gallons of production capacity utilized, subject to future adjustment based on consumer price index changes. We must also pay a royalty to the landlord for each gallon of LNG produced at the facility, as well as a fee for certain other services that the landlord provides.

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Item 3.—Quantitative and Qualitative Disclosures about Market Risk

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

Commodity 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 weather conditions, overall economic conditions and foreign and domestic governmental regulation and relations.

Natural gas costs represented 28.8% (or 33.9% excluding Clean Energy Compression and our Wyoming Northstar Incorporated subsidiary (together with its affiliated entities “Clean Energy Cryogenics”) of our cost of sales for 2014 and 28.3% (or 32.0% excluding Clean Energy Compression and Clean Energy Cryogenics) of our cost of sales for the six months ended June 30, 2015.

To reduce price risk caused by market fluctuations in natural gas, we may enter into exchange traded natural gas futures contracts. These arrangements also expose us to the risk of financial loss in situations where the other party to the contract defaults on the contract or there is a change in the expected differential between the underlying price in the contract and the actual price of natural gas we pay at the delivery point. We did not have any futures contracts outstanding at June 30, 2015.

Foreign Exchange Rate Risk

Because we have foreign operations, we are exposed to foreign currency exchange gains and losses. Since the functional currency of our foreign operations is in their local currency, the currency effects of translating the financial statements of those foreign subsidiaries, which operate in local currency environments, are included in the accumulated other comprehensive loss component of consolidated equity in our condensed consolidated financial statements and do not impact earnings. However, foreign currency transaction gains and losses not in our subsidiaries’ functional currency do impact earnings and resulted in approximately $0.8 million of gains in the six months ended June 30, 2015. During the six months ended June 30, 2015, our primary exposure to foreign currency rates related to our Canadian operations that had certain outstanding accounts receivable and accounts payable denominated in the U.S. dollar which were not hedged.

We have prepared a sensitivity analysis to estimate our exposure to market risk with respect to our monetary transactions denominated in a foreign currency. If the exchange rate on these assets and liabilities were to fluctuate by 10% from the rate as of June 30, 2015, we would expect a corresponding fluctuation in the value of the assets and liabilities of approximately $0.1 million.

Item 4.—Controls and Procedures

Disclosure Controls and Procedures

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in the reports we file or submit under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission 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, under the supervision of and with the participation of our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective at the reasonable assurance level described above as of the end of the period covered by this report.

Changes in Internal Control over Financial Reporting

We regularly review and evaluate our system of internal control over financial reporting and make changes to our processes and systems to improve controls and increase efficiency, while ensuring that we maintain an effective internal control environment. Changes may include such activities as implementing new, more efficient systems, consolidating activities, and migrating processes.

There were no changes in our internal control over financial reporting that occurred during the period covered by this report that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II.—OTHER INFORMATION

Item 1. Legal Proceedings

We are or may become party to various legal actions that have arisen in the ordinary course of our business. During the course of our operations, we are also subject to audit by tax authorities for varying periods in various federal, state, local, and foreign tax jurisdictions. Disputes have arisen, and may continue to arise, during the course of such audits as to facts and matters of law. It is impossible to determine the ultimate liabilities that we may incur resulting from any such lawsuits, claims and proceedings, audits, commitments, contingencies and related matters or the timing of these liabilities, if any. If these matters were to ultimately be resolved unfavorably, an outcome not currently anticipated, it is possible that such outcome could have a material adverse effect upon our consolidated financial position, results of operations or liquidity. However, we believe that the ultimate resolution of such matters will not have a material adverse effect on our consolidated financial position, results of operations, or liquidity.

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 decide to purchase shares of our common stock. We believe the risks and uncertainties described below are the most significant we face. The occurrence of any of the following 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. Additional risks and uncertainties not presently known to us or that we currently deem immaterial may also impair our operations.

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

For the six months ended June 30, 2015, we incurred pre-tax losses of $60.3 million, which included a derivative gain of $0.6 million related to marking to market the value of our Series I warrants (see note 17 to our condensed consolidated financial statements included in this report). In 2012, 2013 and 2014, we incurred pre-tax losses of $99.6 million, $63.2 million, and $89.8 million, respectively. Our losses for 2012, 2013 and 2014 included derivative gains of $3.4 million, $0.9 million, and $5.7 million, respectively. During 2013 and 2014, our losses were substantially decreased by approximately $45.4 million and $28.4 million of revenue, respectively, from federal fuel tax credits, and the program under which we received such credits expired on December 31, 2014. We may never achieve or maintain profitability and our failure to do so would adversely affect our business, prospects and financial condition, and may cause the price of our common stock to fall.

Servicing our debt requires a significant amount of cash, and we may not have sufficient cash flow from our business to pay our debt.

At June 30, 2015, our total consolidated indebtedness was $575.7 million, including an aggregate of $295.0 million principal amount of the 7.5% Notes and the SLG Notes (each as defined in note 12 to our condensed consolidated financial statements included in this report), which are convertible notes we issued in July 2011, August 2011, July 2012, and June 2013 bearing interest at a rate of 7.5% per annum (the “Series 2011 Notes”), and an aggregate of $250.0 million principal amount of the 5.25% Notes (as defined in note 12 to our condensed consolidated financial statements included in this report), which are convertible notes we issued in September 2013 bearing interest at a rate of 5.25% per annum (the “Series 2013 Notes”). Further, as of June 30, 2015, our majority-owned subsidiary NG Advantage LLC (“NG Advantage”) had outstanding debt totaling $10.6 million. We expect our total consolidated interest payment obligations relating to our indebtedness to be approximately $36.8 million for the year ending December 31, 2015. Approximately $3.4 million, $150.1 million, $5.5 million, $305.1 million, $54.6 million and $53.1 million of our consolidated indebtedness matures in 2015, 2016, 2017, 2018, 2019 and 2020, respectively. Our ability to make scheduled payments of the principal of and interest on our indebtedness depends on our future performance, which is subject to economic, financial, competitive and other factors, including those described in these risk factors, many of which are beyond our control. Our business may not generate cash flow from operations in the future sufficient to service our debt. If we are, or if we expect that we will be, unable to generate such cash flow, we may be required to adopt one or more alternatives, such as selling assets, restructuring debt or obtaining additional equity capital on terms that may be onerous to us or highly dilutive to our stockholders. Our ability to refinance our indebtedness, should we decide to do so, will depend on the capital markets and our financial condition at such time. We may not be able to engage in any of these activities or engage in these activities on desirable terms or at the desirable time, which could result in a default on our debt obligations. Additionally, our existing and future indebtedness may contain various restrictive covenants, and any failure by us to comply with any of these covenants could also cause us to be in default under the agreements governing the indebtedness. In the event of any such default, the holders of the indebtedness could, among other things, elect to declare all amounts owed immediately due and payable, which could cause all or a large portion of our available cash flow to be used to pay such amounts and thereby reduce the amount of cash available to pursue our business plans or force us into bankruptcy or liquidation. In addition, the substantial amount of our indebtedness, combined with our other financial obligations and contractual commitments, could have other important consequences. For example, it could make us more vulnerable to adverse changes in general U.S. and worldwide

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economic, industry and competitive conditions and adverse changes in government regulation, limit our flexibility to plan for, or react to, changes in our business and industry, place us at a disadvantage compared to our competitors who have less debt or limit our ability to borrow additional amounts. Further, we are permitted to repay the Series 2011 Notes at maturity with shares of our common stock rather than cash, with the amount of shares determined by the then-current trading price of our common stock, and any such issuances would increase the number of our outstanding shares, thereby diluting the ownership interest of our stockholders.

Our success is dependent upon fleets’ and other consumers’ willingness to adopt natural gas as a vehicle fuel.

Our success is highly dependent upon the adoption by fleets and other consumers of natural gas as a vehicle fuel. If the market for natural gas as a vehicle fuel does not develop as we expect or develops more slowly than we expect, or if a market does develop 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 will be harmed. The market for natural gas as a vehicle fuel is a relatively new, rapidly evolving market characterized by intense competition, evolving government regulation and industry standards and changing consumer demands and behaviors.

Factors that may influence the adoption of natural gas as a vehicle fuel include, among others:

· Increases, decreases or volatility in the price of oil, gasoline, diesel and natural gas;

· The availability of natural gas and the price of natural gas compared to gasoline, diesel and other vehicle fuels;

· Natural gas vehicle cost, availability, quality, safety, design and performance, all relative to other vehicles;

· Improvements in the fuel economy or greenhouse gas emissions of gasoline or diesel engines;

· The entry or exit of engine manufacturers from the market;

· Perceptions about greenhouse gas emissions (also known as “fugitive methane emissions”) from natural gas production and transportation methods, natural gas fueling stations and natural gas vehicles;

· The availability and acceptance of other alternative fuels and alternative fuel vehicles;

· Access to natural gas fueling stations and the convenience and cost to fuel a natural gas vehicle;

· The availability of service for natural gas vehicles;

· The environmental consciousness of fleets and consumers;

· The existence and success of government incentives and grant programs that promote the use of natural gas as a vehicle fuel; and

· Concerns with the content of the natural gas supplied to natural gas fueling stations by utilities and third-party marketers.

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

In the recent past, the prices of oil, gasoline, diesel and natural gas have been volatile, and this volatility may continue. Market adoption of compressed natural gas (“CNG”), liquefied natural gas (“LNG”) and renewable natural gas (“RNG”) as vehicle fuels could be slowed, curtailed or otherwise limited if there are significant decreases in the prices of, or significant increases in the supply and availability of, gasoline and diesel, today’s most prevalent and conventional vehicle fuels, which would decrease the market’s perception of a need for alternative vehicle fuels generally, or if there are decreases in the prices of gasoline and diesel without a corresponding decrease in the price of natural gas or an increase in the price of natural gas without corresponding increases in the prices of gasoline and diesel. The occurrence of any of these circumstances could cause the success or perceived success of our industry and our business to materially suffer. Part of the reason that such slowed, curtailed or limited adoption of natural gas as a vehicle fuel might occur under these circumstances is due to the higher cost of natural gas vehicles compared to gasoline or diesel-powered vehicles, as the components needed for a vehicle to use natural gas add to a vehicle’s base cost. If gasoline or diesel prices drop significantly, fuel economy of gasoline- or diesel-powered vehicles improves, or the prices of CNG and LNG are not sufficiently low, operators may delay or avoid the purchase of natural gas vehicles or decide not to convert their existing vehicles to run on natural gas because of a perceived inability to recover in a timely manner the additional costs of acquiring or converting to natural gas

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vehicles. In addition, our profit margins are directly affected by fluctuations in natural gas, gasoline and diesel prices. In order to attract fleet operators and other consumers to convert to natural gas vehicles, we must be able to offer CNG and LNG fuel at prices significantly lower than gasoline and diesel. Decreases in the price of gasoline and diesel and increases in the price of natural gas make it more difficult for us to offer our customers attractive prices for CNG and LNG as compared to gasoline and diesel prices and maintain an acceptable margin on our sales. Further, increased natural gas prices affect the cost to us of natural gas and adversely impact our operating margins in cases where we cannot pass the increased costs on to our customers, and conversely, lower natural gas prices reduce our revenues in cases where the commodity cost is passed through to our customers.

Among the factors that can cause fluctuations in gasoline, diesel and natural gas prices are changes in domestic and foreign supplies and availability of crude oil and natural gas, domestic storage levels, price and availability of alternative fuels, weather conditions, negative publicity surrounding natural gas drilling techniques or methods or production and importing of oil, level of consumer demand, economic conditions, the price of foreign imports, and domestic and foreign governmental regulations and political conditions. With respect to natural gas supply, there have been recent efforts to place new regulatory requirements on the production of natural gas by hydraulic fracturing of shale gas reservoirs and on transporting and dispensing natural gas. Hydraulic fracturing and horizontal drilling techniques has resulted in a substantial increase in the proven natural gas reserves in the United States, and any changes in regulations that make it more expensive or unprofitable to produce natural gas through such techniques or others, as well as any changes to the regulations relating to transporting or dispensing natural gas, could lead to increased natural gas prices. Additionally, crude oil prices have recently been subject to extreme volatility and decreases, due in part to over-production and increased supply without a corresponding increase in demand. If these circumstances continue, or if all or some combination of the factors contributing to volatile natural gas, oil and diesel prices were to occur or worsen, we could be materially harmed.

If trucks using the Cummins Westport ISX 12G natural gas engine (or a comparable engine) are not adopted by truck operators as quickly or to the extent we anticipate, our results of operations and business prospects will be adversely affected.

We believe the development and expansion of the U.S. natural gas heavy-duty truck market, and the execution of our initiative to build a nationwide network of natural gas truck friendly fueling stations (we refer to this network as “America’s Natural Gas Highway” or “ANGH”), depends upon the successful adoption of the Cummins Westport ISX 12G natural gas engine (or a comparable engine) and the development of a meaningful market in the U.S. for heavy-duty natural gas trucks. Manufacturers may not produce natural gas engines and truck operators may not adopt and deploy natural gas trucks in meaningful numbers or as quickly as we anticipate. Heavy-duty trucks powered by natural gas engines cost more, as compared to comparable gasoline or diesel trucks, and may experience, or be perceived to experience, more operational or performance issues. Our business could be harmed if meaningful numbers of natural gas heavy-duty truck engines are not deployed, if such deployment is slower than expected, or if a meaningful number of the trucks that are deployed are not fueled at our stations.

The failure of our America’s Natural Gas Highway initiative and our inability to achieve our goal to fuel a substantial number of natural gas heavy-duty trucks would materially and adversely affect our financial results and business.

We are seeking to fuel a substantial number of natural gas heavy-duty trucks, and in connection with that effort we are building America’s Natural Gas Highway. Our objectives to fuel a substantial number of heavy-duty trucks and build America’s Natural Gas Highway have required, and will continue to require, a significant commitment of capital and other resources, and our ability to successfully execute our plans faces substantial risks, including, among others:

· Many of our ANGH stations were initially built to provide LNG and LNG costs more than CNG on an energy equivalent basis. If CNG becomes the preferred fuel for truck operators, we will be required to spend significant additional capital to add CNG fueling capability to many of our ANGH stations, and we may not have sufficient capital for that purpose;

· Our ANGH stations may experience mechanical or operational difficulties, which could require significant costs to repair and could reduce customer confidence in our stations;

· Truck and vehicle operators may not fuel at our stations due to lack of access or convenience, prices, concerns with natural gas content or reliability or numerous other factors;

· We have no influence over the development, production, cost or availability of natural gas trucks powered by engines that are well-suited for the U.S. heavy-duty truck market. At June 30, 2015, there was only one principal natural gas engine manufacturer for the medium- and heavy-duty market, Cummins Westport (“CWI”). We have no control over whether CWI will remain in the natural gas engine business or whether other manufacturers will enter the natural gas engine business;

· Operators may not adopt heavy-duty natural gas trucks due to cost, actual or perceived performance issues, or other factors that are outside our control;

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· We may not be able to obtain acceptable margins on fuel sales at ANGH stations; and

· Many ANGH stations (approximately 48 stations at June 30, 2015) were completed before there were sufficient numbers of customers to fuel at the stations, and if such customers do not materialize, we will continue to have substantial investments in assets that do not produce revenues equal to or greater than their costs and we may lose money on LNG that is supplied to the stations but is not purchased by customers.

We must effectively manage these risks and any other risks that may arise in connection with the ANGH build-out to successfully execute our business plan. If the U.S. market for heavy-duty natural gas trucks does not develop or if we fail to successfully execute our ANGH initiative and fuel a substantial number of natural gas heavy-duty trucks, our financial results, operations and business, and our ability to repay our debt, will be materially and adversely affected.

Automobile and engine manufacturers produce very few natural gas vehicles and engines for the United States and Canadian markets, which limits our customer base and our sales of CNG, LNG and RNG.

Limited availability of natural gas vehicles and engine sizes, including heavy-duty trucks and other types of vehicles, restricts their large-scale introduction and narrows our potential customer base. Original equipment manufacturers produce a relatively small number of natural gas engines and vehicles in the U.S. and Canadian markets, and they may not decide to expand, or they may decide to discontinue or curtail, their existing natural gas engine or vehicle product lines. A limited supply of natural gas vehicles limits our customer base and natural gas fuel sales and encourages existing manufacturers to charge a premium for such vehicles, thereby restricting our ability to promote natural gas vehicles.

We may need to raise additional debt or equity capital to continue to fund the growth of our business.

At June 30, 2015, we had total cash and cash equivalents of $53.3 million and short-term investments of $128.6 million. Our business plan calls for approximately $33.8 million in capital expenditures from July 1, 2015 through the end of 2015, as well as capital expenditures thereafter. We may also require capital to make principal or interest payments on our indebtedness or for unanticipated expenses, mergers and acquisitions and strategic investments. As a result, we may find it necessary to raise additional capital through selling assets or pursuing debt or equity financing.

Asset sales and equity or debt financing options may not be available when needed or on terms favorable to us, or at all. Any sale of our assets may limit our operational capacity and could limit or eliminate any business plans that are dependent on the sold assets. Additional issuances of our common stock or securities convertible into our common stock would increase the number of our outstanding shares, thereby diluting the ownership interest of our stockholders. We may also pursue debt financing since, despite our level of consolidated debt, the agreements governing much of our existing debt do not restrict our ability to incur additional indebtedness, including secured and unsecured indebtedness, or require us to maintain financial ratios or specified levels of net worth or liquidity. Debt financing options that we may pursue include, among others, equipment financing, the sale of convertible notes, high yield debt, asset -based loans, term loans, project finance debt, municipal bond financing or commercial bank financing. Any debt financing we obtain may require us to make significant interest payments and to pledge some or all of our assets as security. In addition, if we incur additional indebtedness in the future, these higher levels of indebtedness could increase the risk that we would be unable to repay our debt or make other required payments and could adversely affect our creditworthiness, which could limit our ability to obtain further debt or equity financing as needed and restrict our flexibility in responding to changing business and economic conditions, any of which could negatively impact our business and prospects. On the other hand, if we are unable to obtain capital in amounts sufficient to fund our contractual obligations, our business plan, and any unanticipated expenses, capital expenditures, mergers, acquisitions or strategic investments, we would be forced to suspend, delay or curtail these capital expenditures or other transactions.

Our business is influenced by environmental, tax and other government regulations, programs and incentives promoting cleaner burning fuels and alternative vehicles, and their modification or repeal could adversely impact our business.

Our business is influenced by federal, state and local government tax attributes, credits, rebates, grants and similar programs and incentives that promote the use of natural gas and RNG as a vehicle fuel, as well as by laws, rules and regulations that require reductions in carbon emissions. Industry participants with a vested interest in gasoline and diesel or alternative fuels such as hydrogen- or electric-powered vehicles, many of which have substantially greater resources than we have, invest significant time and money in efforts to influence environmental regulations in ways that could delay or repeal regulations and programs that promote natural gas as a vehicle fuel. Any failure to adopt, delay in implementing, expiration, repeal or modification of federal, state or local regulations, programs or incentives that encourage the use of natural gas and RNG as a vehicle fuel would harm our operating results and financial condition. For example, some such government programs and incentives have recently expired, such as the federal fuel tax credit (“VETC”) of $0.50 per gasoline gallon equivalent of CNG and LNG sold for vehicle fuel use, which expired December 31, 2014 and

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has not been reinstated. In 2013 and 2014 we received approximately $45.4 million and $28.4 million of revenue, respectively, related to VETC fuel tax credits, representing approximately 12.9% and 6.6%, respectively, of our total revenue during the periods. Additionally, changes to or the repeal of laws, rules and regulations that mandate reductions in carbon emissions and/or the use of renewable fuels, including the California Low Carbon Fuel Standard and the federal Renewable Fuel Standard Phase 2, under which we generate credits (“LCFS Credits” and “RIN Credits” or “RINs”, respectively) by selling natural gas and RNG as a vehicle fuel, would adversely affect our financial condition. For example, the staff of the California Air Resources Board recently proposed changes to its carbon intensity number for CNG, LNG and RNG to take into account alleged system-wide methane losses, which changes, if implemented, would result in fewer carbon benefits associated with use of natural gas as a vehicle fuel and would adversely affect our business. Further, our business would be adversely affected if grant funds cease to be available under government programs for the purchase and construction of natural gas vehicles and stations.

We face increasing competition from oil and gas producers, developers of natural gas fueling station infrastructure, other alternative fuel and alternative vehicle companies, fuel providers, refuse companies, industrial gas companies, natural gas utilities and their affiliates, fuel station and truck stop owners and other organizations that may have far greater resources and brand awareness than we have.

A significant number of established businesses, including oil and gas companies, developers of natural gas fueling station infrastructure, alternative vehicle and alternative fuel companies, refuse collectors, natural gas utilities and their affiliates, industrial gas companies, truck stop and fuel station owners, fuel providers and other organizations have entered or are planning to enter the markets for natural gas and other alternatives for use as vehicle fuels. Additionally, for certain of our key customer markets, such as airports, taxis and paratransit vehicles, we indirectly compete with companies such as Uber and Lyft that provide alternative transportation methods that may limit these markets generally. Many of these current and potential competitors have substantially greater financial, marketing, research and other resources than we have. Further, new technologies and improvements to existing technologies may make alternatives other than natural gas more attractive to the market, or may slow the development of the market for natural gas as a vehicle fuel if such advances are made with respect to oil and gas usage. Natural gas utilities also own and operate natural gas fueling stations that compete with our stations. The California Public Utilities Commission has approved a compression services tariff application by the Southern California Gas Company, allowing the utility to compete with us by building and owning natural gas compression equipment on customer property and by providing operation and maintenance services to customers. Further, utilities in several other states, including Michigan, Illinois, New Jersey, North Carolina, Oregon, Maryland, Washington, Kentucky, Florida and Georgia, either have or are preparing to enter the natural gas vehicle fuel business. Utilities, in particular, have unique competitive advantages, including their typically lower cost of capital, substantial and predictable cash flows, long-standing customer relationships, greater brand awareness and large and well-trained sales and marketing organizations.

We expect competition to intensify in the near term in the alternative vehicle fuels market generally and, assuming the use of natural gas vehicles and the demand for natural gas vehicle fuel increases, the market for natural gas vehicle fuel. Increased competition will lead to amplified pricing pressure and reduced operating margins.

If there are advances in other alternative vehicle fuels or technologies, or if there are improvements in gasoline, diesel or hybrid engines, demand for natural gas vehicles may decline.

Technological advances in the production, delivery and use of alternative fuels that are, or are perceived to be, cleaner, more cost-effective or more readily available than CNG, LNG or RNG have the potential to slow or limit adoption of natural gas vehicles. Advances in gasoline and diesel engine technology, including efficiency improvements and further hybrid development, may offer a cleaner, more cost-effective option and make fleet customers less likely to convert their fleets to natural gas. Technological advances related to ethanol or biodiesel, which are used as an additive to, or substitute for, gasoline and diesel fuel, may slow the need to diversify fuels and affect the growth of the natural gas vehicle market. Use of electric heavy-duty trucks, buses and trash trucks, or the perception that such vehicles may soon be widely available and provide satisfactory performance, may reduce demand for natural gas vehicles. In addition, hydrogen and other alternative fuels in experimental or developmental stages may offer a cleaner, more cost-effective alternative to gasoline and diesel than natural gas. Advances in technology that slow or curtail the growth of or conversion to natural gas vehicles, or that otherwise reduce demand for natural gas as a vehicle fuel, will have an adverse effect on our business. Failure of natural gas vehicle technology to advance at a sufficient pace may also limit its adoption and our ability to compete with other alternative fuels and alternative vehicles.

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We are subject to risks associated with station construction and similar activities, including difficulties identifying suitable station locations, zoning, permitting or other local resistance, cost overruns, delays, and other contingencies.

In connection with our station construction operations, we may not be able to identify, obtain and retain sufficient permits, approvals and other rights to use suitable locations for the stations we or our customers seek to build. We may also encounter land use or zoning difficulties or other local resistance with respect to stations that prohibit us or our customers from building new stations on preferred sites or limit or restrict the use of new or existing stations. Any such difficulties, resistance or limitations could harm our business and results of operations. In addition, we act as the general contractor and construction manager for station construction and facility modification projects and 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 our projects. Shortages of skilled subcontractor labor for our projects could significantly delay a project or otherwise increase our costs. Our profit on our projects is based in part on assumptions about the cost of the projects. Cost overruns, delays or other execution issues may, in the case of projects that 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 that we build and own, result in our failure to achieve an acceptable rate of return.

Our manufacturing operations could subject us to significant costs and other risks, including product liability claims.

Our subsidiary Clean Energy Compression, formerly known as IMW, designs, manufactures, sells and services non-lubricated natural gas compressors and related equipment used in CNG stations. The equipment Clean Energy Compression produces and sells has not in some instances performed, and may not in the future perform, as expected, according to legal or other specifications, or at all. Clean Energy Compression has in the past and may in the future incur significant and unexpected costs in the life cycle of its products, including costs incurred to fix any discovered performance errors and to repair any product malfunctions. The scope and likelihood of these risks continues to increase as Clean Energy Compression makes efforts to expand its services to new geographic and other markets. The occurrence of any of these risks has and may continue to damage our customer relationships and reputation, delay the launch of new Clean Energy Compression products, force product recalls and/or result in product liability claims.

Our warranty reserves may not adequately cover our warranty obligations.

We provide product warranties with varying terms and durations for natural gas compressors and stations we build and sell to customers, and we establish reserves for the estimated liability associated with our product warranties. Our warranty reserves are based on historical trends as well as our understanding of specifically identified warranty issues. The amounts estimated could differ materially from warranty costs that may ultimately be realized. We would be adversely affected by an increase in the rate of warranty claims, the average amount involved with each warranty claim or the occurrence of unexpected warranty claims.

Increased IT security threats and more sophisticated and targeted computer crime could pose a risk to our systems, networks, products, solutions and services.

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. Depending on their nature and scope, such threats could potentially lead to the compromise of confidential information, improper use of our systems and networks, manipulation and destruction of data and operational disruptions.

The global scope of our operations exposes us to additional risks and uncertainties.

Our Clean Energy Compression subsidiary has operations in a number of countries, including Canada, China, Colombia, Bangladesh and Peru. Clean Energy Compression’s natural gas compression equipment is primarily manufactured in Canada and sold globally, which exposes us to a number of risks that can arise from international trade transactions, local business practices and cultural considerations. In addition to the other risks described in these risk factors, the global scope of our operations may subject us to risks and uncertainties that may limit our operations, increase our costs or otherwise negatively impact our business and financial condition, including, among others:

· Failure to comply with the United States Foreign Corrupt Practices Act and other applicable anti-bribery laws;

· Political unrest, terrorism, war, natural disasters and economic and financial instability;

· Cheap local oil, gasoline or diesel;

· Unexpected changes in regulatory requirements and uncertainty related to developing legal and regulatory systems with respect to economic and business activities, real property ownership and application of contract rights;

· Trade restrictions and import-export regulations;

· Difficulties enforcing agreements and collecting receivables;

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· Difficulties complying with the laws and regulations of multiple jurisdictions;

· Difficulties ensuring that health, safety, environmental and other working conditions are properly implemented and/or maintained by the local office;

· Differing employment practices and/or labor issues, including wage inflation, labor unrest and unionization policies;

· Limited intellectual property protection;

· Longer payment cycles by international customers;

· Inadequate local infrastructure and disruptions of service from utilities or telecommunications providers, including electricity shortages; and

· Potentially adverse tax consequences.

In addition to the above, we also face risks associated with currency exchange and convertibility, inflation and repatriation of earnings as a result of our foreign operations. In some countries, economic, monetary and regulatory factors could affect our ability to convert funds to United States dollars or move funds from accounts in these countries. We are also vulnerable to appreciation or depreciation of foreign currencies against the United States dollar, which could negatively impact our operating results and financial performance.

We depend on key people to operate our business, and if we are unable to retain our key people or hire additional qualified people, our ability to develop and successfully market our business would be harmed.

We believe that our future success is highly dependent on the contributions of our executive officers, as well as our ability to attract and retain highly skilled managerial, sales, technical and finance personnel. Qualified individuals are in high demand, and we may incur significant costs to attract and retain them. All of our executive officers and other United States employees may terminate their employment relationships with us at any time, and their knowledge of our business and industry would be extremely difficult to replace. If we are unable to retain our executive officers and key employees or, if such individuals leave our company, we are unable to attract and successfully integrate quality replacements, our business, operating results and financial condition could be harmed.

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

We have, and will continue to seek, long-term CNG, LNG and RNG station construction, maintenance and fuel sales contracts with various governmental bodies, which accounted for approximately 20.9% of our revenues for the six months ended June 30, 2015 and approximately 33%, 19% and 18% of our annual revenues in 2012, 2013 and 2014, respectively. In addition to normal business risks, our contracts with these government entities are often subject to unique risks, some of which are beyond our control. Long-term government contracts and related orders are subject to cancellation if adequate appropriations for subsequent performance periods are not made. The termination of funding for a government program supporting any of our government contracts could result in a loss of anticipated future revenues attributable to that contract, which could have a negative impact on our operations. In addition, government entities with which we contract are often able to modify, curtail or terminate contracts with us without prior notice at their convenience, and are only liable for payment for work done and commitments made at the time of termination. Modification, curtailment or termination of significant contracts could have a material adverse effect on our results of operations and financial condition. Further, 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 certain 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 such protests.

We may never initiate or complete construction of the GE Plants. If we commence construction of either GE Plant, we may encounter difficulties building them and we would need to comply with significant obligations to GE.

Our ability to commence development and construction of two LNG plants (the “GE Plants”), to be financed under our credit agreement with General Electric Capital Corporation (“GE”), will depend on our satisfaction of a number of conditions, including the availability of sites upon which to construct the GE Plants, our ability to acquire title to, or leasehold interests in, such sites and the receipt of all governmental approvals necessary to design, develop, own, construct, install, operate and maintain the GE Plants. If we do not satisfy all of the conditions by December 31, 2016, GE’s obligation to fund the GE Plants will terminate.

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If we commence construction of either GE Plant, we may not be able to comply with all of our obligations to GE under the applicable credit agreement. For example, we may not complete one or both of the GE Plants within the required time period, or we may not make our required equity contributions to the GE Plants, which consist of all funding required to complete the plants in excess of the $200 million to potentially be loaned to us by GE. The GE Plants may cost more than we expect, and we may not be able to pay any additional costs. If the GE Plants are completed, they may not generate enough cash flow to pay our obligations to GE because they may experience operational difficulties or inefficiencies or we may not be able to sell enough of the LNG the GE Plants produce. If we construct the GE Plants and we do not fulfill our obligations to GE, we would lose some or all of our investments in the GE Plants.

We may experience difficulty procuring sufficient LNG.

Production of LNG in the United States is fragmented and limited. It may be difficult for us to obtain LNG without interruption and near our current or target markets at competitive prices, when needed, or at all. If LNG liquefaction plants we own, or if any from which we purchase LNG, are damaged by severe weather, earthquakes or other natural disasters or otherwise experience prolonged down time; or if any such plants cannot produce LNG meeting applicable composition specifications and requirements; our LNG supply will be restricted. If we are unable to supply enough LNG that satisfies applicable specifications (either from our own plants or by purchasing it from third parties) to meet customer demand, we may lose customers and/or be liable to our customers for penalties and damages. Furthermore, because transportation of LNG is relatively expensive, if we are required to supply LNG from distant locations and cannot pass these costs through to our customers, our operating margins will decrease due to our increased transportation costs.

LNG supply purchase commitments may exceed demand, causing our costs to increase.

We are a party to one long-term LNG supply agreement that has a take-or-pay commitment, and we may enter into additional contracts with take-or-pay commitments in the future. Take-or-pay commitments require us to pay for the LNG that we have agreed to purchase irrespective of whether we can sell the LNG. Should the market demand for LNG decline or fail to develop as we anticipate, if we lose significant LNG customers, if demand under any existing or any future LNG sales contract does not maintain its volume levels or grow, or if future demand for LNG otherwise does not meet our expectations, these commitments may cause our operating and supply costs to increase without a corresponding increase in revenue and our margins may be negatively impacted.

Compliance with potential greenhouse gas regulations affecting our LNG plants, fueling stations or fuel sales may prove costly and negatively affect our financial performance.

California has adopted legislation, AB 32, which calls for a cap on greenhouse gas emissions throughout California and a statewide reduction to 1990 levels by 2020 and an additional 80% reduction below 1990 levels by 2050. The Governor of California recently issued an executive order mandating a reduction in greenhouse gas emission by 40% compared to 1990 levels by 2030. Beginning January 1, 2015, AB 32 specifically began regulating the greenhouse gas emissions from transportation fuels including the emissions associated with LNG and CNG vehicle fuel.

Under AB 32, the LNG vehicle fuel provider is the regulated party with respect to LNG vehicle fuel use. Our costs for complying with AB 32 with respect to our LNG vehicle fuel sales in California are unknown at this time and will depend on how much LNG vehicle fuel we sell that is regulated, the California Air Resource Board’s guidance on the regulation of LNG vehicle fuel and the cost of carbon credits under AB 32 at the time we purchase them. Ultimately we anticipate that the costs we incur will be passed through to our LNG vehicle fuel purchasers, and this may diminish the attractiveness of LNG as a vehicle fuel for California buyers.

With respect to CNG, the regulated party under AB 32 is the utility that owns the pipe through which the fossil fuel natural gas is sold. The utilities have been granted a significant amount of carbon credits to cover their compliance costs through 2020. We anticipate, however, that over time, as the allocation of free credits to the utilities declines, we or our CNG customers will be required to pay more for CNG vehicle fuel to cover the AB 32 compliance costs of the utility. These costs will be determined by the amount the utility spends to buy any carbon credits to comply with AB 32 with respect to natural gas we or our customers buy through their pipeline.

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With respect to sales of Redeem, our RNG vehicle fuel, we believe that biofuels like Redeem are generally exempt from regulation under AB 32. However, due to the complexity and uncertainty surrounding the requirements that biomethane must meet in order to be exempt under AB 32, and the possibility of changes in the regulation, the Redeem we sell may not be exempt under AB 32. Any Redeem volumes that are not exempt will incur compliance costs commensurate with sales of CNG and LNG derived from fossil fuel natural gas.

Other states and the federal government are considering passing similar measures to regulate and reduce greenhouse gas emissions. Any of these regulations, when and if implemented, may also regulate the greenhouse gas emissions produced by our LNG production plants, our CNG and LNG fueling stations or our RNG production facilities, or regulate the greenhouse gas emissions associated with the LNG, CNG and RNG we sell, and require that we obtain emissions credits or invest in costly emissions prevention technology. We cannot currently estimate the potential costs associated with compliance with federal, state or local regulation of greenhouse gas emissions and these unknown costs are not contemplated by our current customer agreements. If any of these regulations are implemented, our associated compliance costs may have a negative impact on our financial performance, reduce our margins and impair our ability to fulfill customer contracts. Further, these regulations may discourage consumers from adopting natural gas as a vehicle fuel.

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

Our operations entail inherent risks, including equipment defects, malfunctions and failures, which could result in uncontrollable flows of natural gas, fires, explosions and other damages. For example, operation of LNG pumps requires special training because of the extreme low temperatures of LNG. LNG tanker trailers have also in the past been, and may in the future be, involved in accidents that result in explosions, fires and other damage. Further, improper refueling of natural gas vehicles can result in venting of methane gas, which is a potent greenhouse gas, and such methane emissions may in the future be regulated by the U.S. Environmental Protection Agency (“EPA”) or by state regulatory agencies. Additionally, CNG fuel tanks and trailers, if damaged by accidents or improperly maintained or installed, may rupture and the contents of the tank or trailer may rapidly decompress and result in death or serious injury. These risks may expose us to liability for personal injury, wrongful death, property damage, pollution and other environmental damage. We may incur substantial liability and cost if damages are not covered by insurance or are in excess of policy limits.

We provide financing to fleet customers for natural gas vehicles, which exposes our business to credit risks.

We lend to certain qualifying customers a portion of, and occasionally up to 100% of, the purchase price of natural gas vehicles. We may also lease vehicles to customers. Risks associated with these financing activities include, among others, the following: the equipment financed consists mostly of vehicles that are mobile and easily damaged, lost or stolen; the borrower may default on payments, enter bankruptcy proceedings and/or liquidate; we may not be able to bill properly or track payments in an adequate fashion to properly manage this service; and the amount of capital available to us is limited and may not allow us to make loans required by customers. As of June 30, 2015, we had $11.4 million outstanding in loans provided to customers to finance natural gas vehicle purchases.

Our business is subject to a variety of governmental regulations that may restrict our operations and may result in costs and penalties.

We are subject to a variety of federal, state and local laws and regulations relating to foreign business practices, the environment, health and safety, labor and employment, building codes and construction, land use and taxation, among others. It is difficult and costly to manage the requirements of every individual authority having jurisdiction over our various activities and to comply with these varying standards. These laws and regulations are complex, change frequently and have tended to become more stringent over time. Any changes to existing regulations or adoption of new regulations may result in significant additional expense to us and our customers. Further, from time to time, as part of the regular overall evaluation of our operations, including newly acquired or developing operations, we may be subject to compliance audits by regulatory authorities, which may involve significant costs and use of other resources. Also, in connection with our operations, we often need facility permits or licenses to address, among other things, storm water or wastewater discharges, waste handling, and air emissions, which may subject us to onerous or costly permitting conditions.

Our failure to comply with any applicable laws and regulations may result in a variety of administrative, civil and criminal enforcement measures, including assessment of monetary penalties and the imposition of corrective requirements. In addition, our failure to comply with regulations related to the government procurement process at the federal, state or local level or restrictions on political activities and lobbying may result in administrative or financial penalties, including being barred from providing services to governmental entities.

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Our RNG business may not be successful.

We own RNG production facilities located in Canton, Michigan and North Shelby, Tennessee. We are also seeking to increase our RNG business by pursuing additional projects on our own and with project partners. We may not be successful in operating or developing these projects or any future projects or generating a financial return from our investments. Historically, projects that produce pipeline quality RNG have often failed due to the volatile prices of conventional natural gas, unpredictable RNG production levels, technological difficulties and costs associated with operating the production facilities, and the lack of government programs and regulations that support such activities. The success of our RNG business depends on our ability to obtain necessary financing, to successfully manage the construction and operation of RNG production facilities, to enter RNG supply agreements with third parties, and to either sell RNG at substantial premiums to conventional natural gas prices or to sell, at favorable prices, credits we may generate under federal or state laws, rules and regulations, including RINs and LCFS Credits. If we are not successful at one or more of these activities, our RNG business could fail.

The market for RINs and LCFS Credits is volatile, and the prices for such credits may be subject to significant fluctuations. Further, the value of RINs and LCFS Credits will be adversely affected by any changes to the state and federal programs under which such credits are generated and sold. In the absence of state and federal programs that support premium prices for RNG or that allow us to generate and sell LCFS Credits and RINs or other credits, or if our customers are not otherwise willing to pay a premium for RNG, we may be unable to profitably operate our RNG business.

We have experienced, and may continue to experience, difficulties producing RNG.

We have experienced difficulty producing the expected volumes of RNG at our operating RNG plants due to, among other factors, problems with key equipment, severe weather, landfill conditions and construction delays. These difficulties may continue or worsen in the future, and our ability to produce RNG may be adversely affected by a number of other factors beyond our control, including, among others, limited availability or unfavorable composition of collected landfill gas, failure to obtain and renew necessary permits, landfill mismanagement, problems with our critical equipment, and adverse or severe weather conditions. In addition, we may seek to or be required to upgrade, expand or service our RNG facilities, which may result in plant shutdowns, cause delays that reduce the amount of RNG we produce or involve significant unexpected costs.

We may from time to time pursue acquisitions, investments or other strategic relationships, which could fail to meet expectations.

We may acquire or invest in other companies or businesses. For example, in October 2014, we invested in NG Advantage. In addition, we may pursue other strategic transactions or relationships. For instance, in September 2014, we formed a joint venture with Mansfield Ventures LLC called Mansfield Clean Energy Partners LLC. Acquisitions, investments and other strategic partnerships and relationships involve numerous risks, any of which could harm our business, including, among others, the following: difficulties integrating the technologies, operations, existing contracts and personnel of an acquired company or partner; difficulties in supporting and transitioning vendors, if any, of an acquired company or partner; diversion of financial and management resources from existing operations or alternative acquisition or investment opportunities; failure to realize the anticipated benefits or synergies of a transaction or relationship; failure to identify all of the problems, liabilities or other shortcomings or challenges of a company or technology we may partner with, invest in or acquire, including issues related to intellectual property, regulatory compliance practices, revenue recognition or other accounting practices or employee or customer issues; risks of entering new markets in which we may have limited or no experience; potential loss of key employees, customers and vendors from either our current business or an acquired company’s or partner’s business; inability to generate sufficient revenue to offset acquisition, investment or other related costs; additional costs or equity dilution associated with funding the acquisition, investment or other relationship; and possible write-offs or impairment charges relating to the businesses we partner with, invest in or acquire.

Our quarterly results of operations are difficult to predict and have fluctuated significantly.

Our quarterly results of operations have historically experienced significant fluctuations. Our net losses were approximately $11.3 million, $16.3 million, $41.7 million, $3.9 million, $11.9 million, $18.8 million, $32.3 million, $28.6 million, $32.3 million, $30.1 million, $31.1 million, and $30.0 million, for the three months ended June 30, 2012, September 30, 2012, December 31, 2012, March 31, 2013, June 30, 2013, September 30, 2013, December 31, 2013, March 31, 2014, June 30, 2014, September 30, 2014, March 31, 2015, and June 30, 2015 respectively. In the three months ended December 31, 2014, our net income was $1.3 million. Our quarterly results of operations may fluctuate significantly as a result of a variety of factors, including those described in these risk factors. If our quarterly results of operations fall below the expectations of securities analysts or investors, the price of our common stock could decline substantially. As a result of the significant variances in our operating results in prior periods, period- to-period comparisons of our operating results may not be meaningful and investors in our common stock should not rely on the results of one quarter as an indication of future performance.

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Sales of shares could cause the market price of our stock to drop significantly, even if our business is doing well.

As of June 30, 2015, there were 90,527,189 shares of our common stock outstanding, 10,782,668 shares underlying outstanding options, 2,972,252 shares underlying restricted stock units, 2,130,682 shares underlying outstanding Series I warrants, 5,000,000 shares underlying a warrant we issued in November 2012 to GE, 19,160,338 shares underlying our Series 2011 Notes and 16,025,641 shares underlying our Series 2013 Notes. All of our outstanding shares are eligible for sale in the public market, subject in certain cases to the requirements of Rule 144 of the Securities Act of 1933, as amended (the “Securities Act”). Also, shares issued upon exercise or conversion of outstanding options, warrants and convertible notes are eligible for sale in the public market to the extent permitted by the provisions of the applicable option, warrant and convertible note agreements and Rule 144, or if such shares have been registered for resale under the Securities Act. If these shares are sold, or if it is perceived that they will be sold, in the public market, the trading price of our common stock could decline.

As of June 30, 2015, 18,139,720 shares of our common stock held by our co-founder and board member T. Boone Pickens were pledged as security for loans made to Mr. Pickens. We are not a party to these loans. If the price of our common stock declines, Mr. Pickens may be forced to provide additional collateral for the loans or to sell shares of our common stock in order to remain within the margin limitations imposed under the terms of the loans. Any sales of common stock following a margin call that is not satisfied may cause the price of our common stock to decline further. In addition, a number of our directors and officers have in the past entered into Rule 10b5-1 sales plans with a broker to sell shares of our common stock that they hold or that they may acquire upon the exercise of stock options. Sales under these plans occur automatically without further action by the director or officer once the price, date or other parameters of the particular selling plan are achieved. As of June 30, 2015, no shares were subject to future sales by our directors and officers under these selling plans. If our directors and officers adopt new selling plans and sales of shares under these selling plans occur, the trading price of our common stock could fall.

A significant portion of our stock is beneficially owned by a single stockholder whose interests may differ from yours and who is able to exert significant influence over our corporate decisions, including a change of control.

As of June 30, 2015, our co-founder and board member T. Boone Pickens beneficially owned in the aggregate approximately 24.08% of our common stock (including 18,139,720 outstanding shares of common stock, 705,000 shares underlying stock options exercisable within 60 days after June 30, 2015, and 4,113,923 shares underlying convertible promissory notes convertible within 60 days after June 30, 2015). As a result, Mr. Pickens is able to strongly influence or control matters requiring approval by our stockholders, including the election of directors and mergers, acquisitions or other extraordinary transactions. Mr. Pickens may have interests that differ from yours and may vote in a way with which you disagree and that may be adverse to your interests. This concentration of ownership may have the effect of delaying, preventing or deterring a change of control of our Company, could deprive our stockholders of an opportunity to receive a premium for their stock as part of a sale of our Company, and might ultimately affect the market price of our common stock. Conversely, this concentration may facilitate a change of control at a time when you and other investors may prefer not to sell.

Our stock price may be volatile.

The market price of our common stock has experienced, and may continue to experience, significant volatility. Such volatility may be in response to various factors, some of which are beyond our control. In addition to the other factors discussed in these risk factors, factors that may cause volatility in our stock price include, among others:

· Changes in prices for oil, traditional vehicle fuels such as gasoline and diesel, and natural gas;

· Adoption of and growth of the market for natural gas as a vehicle fuel;

· Our ability to fuel a substantial number of natural gas heavy-duty trucks and other natural gas vehicles;

· Adoption by the U.S. heavy-duty truck market of engines that operate on natural gas;

· Successful implementation of our business plans, including, without limitation, our ANGH initiative;

· Production and supply of LNG and RNG;

· Investor perception of our industry or our prospects;

· Fluctuations in our operating results;

· Sales of our common stock by us, our officers or directors, or significant stockholders;

· A decline in the trading volume of or the price for our common stock;

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· Oil and gas companies, natural gas utilities and others entering the market for natural gas fuel;

· Changes in our key personnel;

· Competitive developments; and

· Changes in general economic and market conditions.

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, and in such instances, 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.

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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

None.

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Item 6.—Exhibits

(a) Exhibits

Exhibit No.		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 Securities and Exchange Act of 1934, 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 Securities and Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1**		Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, executed by Andrew J. Littlefair, President and Chief Executive Officer, and Robert M. Vreeland, Chief Financial Officer.

101*		The following materials from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2015, formatted in XBRL (eXtensible Business Reporting Language):

		(i) Condensed Consolidated Balance Sheets at December 31, 2014 and June 30, 2015;
		(ii) Condensed Consolidated Statements of Operations for the Three Months and Six Months Ended June 30, 2014 and 2015;
		(iii) Condensed Consolidated Statements of Comprehensive Loss for the Three Months and Six Months Ended June 30, 2014 and 2015;
		(iv) Condensed Consolidated Statements of Cash Flows for the Three Months and Six Months Ended June 30, 2014 and 2015; and
		(v) Notes to Condensed Consolidated Financial Statements.

* Filed herewith.

** Furnished herewith.

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SIGNATURE

Pursuant to the requirements of the Securities and 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 5, 2015	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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EXHIBIT INDEX

Exhibit No.		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 Securities and Exchange Act of 1934, 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 Securities and Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1**		Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, executed by Andrew J. Littlefair, President and Chief Executive Officer, and Robert M. Vreeland, Chief Financial Officer.

101*		The following materials from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2015, formatted in XBRL (eXtensible Business Reporting Language):

		(i) Condensed Consolidated Balance Sheets at December 31, 2014 and June 30, 2015;
		(ii) Condensed Consolidated Statements of Operations for the Three Months and Six Months Ended June 30, 2014 and 2015;
		(iii) Condensed Consolidated Statements of Comprehensive Loss for the Three Months and Six Months Ended June 30, 2014 and 2015;
		(iv) Condensed Consolidated Statements of Cash Flows for the Three Months and Six Months Ended June 30, 2014 and 2015; and
		(v) Notes to Condensed Consolidated Financial Statements.

* Filed herewith.

** Furnished herewith.