0001047469-13-001945.txt : 20130228 0001047469-13-001945.hdr.sgml : 20130228 20130228161532 ACCESSION NUMBER: 0001047469-13-001945 CONFORMED SUBMISSION TYPE: 10-K PUBLIC DOCUMENT COUNT: 19 CONFORMED PERIOD OF REPORT: 20121231 FILED AS OF DATE: 20130228 DATE AS OF CHANGE: 20130228 FILER: COMPANY DATA: COMPANY CONFORMED NAME: Clean Energy Fuels Corp. CENTRAL INDEX KEY: 0001368265 STANDARD INDUSTRIAL CLASSIFICATION: GAS & OTHER SERVICES COMBINED [4932] IRS NUMBER: 330968580 STATE OF INCORPORATION: DE FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-K SEC ACT: 1934 Act SEC FILE NUMBER: 001-33480 FILM NUMBER: 13652225 BUSINESS ADDRESS: STREET 1: 3020 OLD RANCH PARKWAY, SUITE 400 CITY: SEAL BEACH STATE: CA ZIP: 90740 BUSINESS PHONE: (562) 493-2804 MAIL ADDRESS: STREET 1: 3020 OLD RANCH PARKWAY, SUITE 400 CITY: SEAL BEACH STATE: CA ZIP: 90740 FORMER COMPANY: FORMER CONFORMED NAME: Clean Energy Fuels, Corp. DATE OF NAME CHANGE: 20060703 10-K 1 a2213180z10-k.htm FORM 10-K
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-K

(Mark One)    

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

For the fiscal year ended: December 31, 2012

or

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

Commission File Number: 001-33480

CLEAN ENERGY FUELS CORP.
(Exact name of registrant as specified in its charter)

Delaware
(State or other jurisdiction of incorporation)		   33-0968580
(IRS Employer Identification No.)

3020 Old Ranch Parkway, Suite 400, Seal Beach CA 90740
(Address of principal executive offices, including zip code)

(562) 493-2804
(Registrant's telephone number, including area code)

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

Title of each class   Name of each exchange on which registered
Common Stock, par value $0.0001 per share   The NASDAQ Global Market

         Securities registered pursuant to section 12(g) of the Act: None

         Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ý    No o

         Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes o No ý

         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 ý 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 (§ 229.405 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 ý No o

         Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. 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 the definitions of "large accelerated filer," "accelerated filer," and "smaller reporting company" in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer ý   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 ý

         The aggregate market value of the voting stock held by non-affiliates of the registrant as of June 30, 2012, the last business day of the registrant's second fiscal quarter, was approximately $1,048,772,532 (based on the closing price reported on such date by The NASDAQ Global Market of the registrant's common stock). Shares of common stock held by officers and directors and holders of 10% or more of the outstanding common stock have been excluded from the calculation of this amount because such persons may be deemed to be affiliates. This determination of affiliate status is not necessarily a conclusive determination for other purposes.

         As of February 22, 2013, the number of outstanding shares of the registrant's common stock was 88,355,226.

DOCUMENTS INCORPORATED BY REFERENCE

         Portions of the registrant's proxy statement for the 2013 Annual Meeting of Stockholders are incorporated herein by reference in Part III of this annual report on Form 10-K to the extent stated herein.

   


CAUTIONARY NOTE REGARDING FORWARD LOOKING STATEMENTS

        Certain statements in this annual report on Form 10-K may constitute "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements are based upon our current assumptions, expectations and beliefs concerning future developments and their potential effect on our business. In some cases, you can identify forward-looking statements by the following words: "may," "will," "could," "would," "should," "expect," "intend," "plan," "anticipate," "believe," "approximately," "estimate," "predict," "project," "potential," "continue," "ongoing," or the negative of these terms or other comparable terminology, although the absence of these words does not necessarily mean that a statement is not forward-looking. We believe that the statements in this annual report on Form 10-K that we make regarding the following subject matters are forward-looking by their nature:

    •
    our ability to capture a substantial share of the significant anticipated growth in the market for natural gas as a vehicle fuel and to enhance our leadership position as that market expands;

    •
    our plan and the projected schedule to build America's Natural Gas Highway;

    •
    development, commercial availability and adoption of new natural gas engines for the U.S. heavy duty over-the-road trucking market including the CWI 11.9 liter engine;

    •
    LNG sourcing and supply;

    •
    the importance of our partnership with General Electric;

    •
    plans to build two LNG plants with General Electric;

    •
    plans to sell RNG we generate and purchase RNG from third party producers as a vehicle fuel;

    •
    our ability to generate and sell RINs and LCFS Credits at prices that enable us to profitably market and sell RNG;

    •
    the potential for the trucking market to become our biggest;

    •
    plans to expand our station network and business with existing customers and to win business with new customers;

    •
    the success of our business of manufacturing and selling natural gas vehicle fuel compression equipment;

    •
    the success and expansion of our business of producing and selling RNG;

    •
    our ability to sell RNG we produce at prices that are at a premium to conventional natural gas prices;

    •
    the success of our natural gas vehicle conversion business;

    •
    the amount of estimated payments to former owners of wholly owned subsidiaries in future years pursuant to the terms of the respective purchase agreements;

    •
    increasing our sales in the trucking, taxi, public transit, refuse hauling and airport markets;

    •
    expanding our business into international markets, and managing our existing international operations;

    •
    plans to participate in state and federal grant programs;

    •
    expansion of our California LNG plant;

    •
    anticipated increased production of RNG at our facility in Dallas, Texas;

    •
    expectations about sales of RNG produced by our facility in Michigan;

2

    •
    construction of our RNG facility in Tennessee;

    •
    strategic benefits of owning BAF and IMW and our other subsidiaries;

    •
    developments and trends and opportunities for growth in the natural gas and fleet vehicle markets, including increased transition from diesel and gasoline powered vehicles to natural gas vehicles;

    •
    more stringent emissions requirements continuing to make natural gas vehicles an attractive alternative to traditional gasoline and diesel powered vehicles;

    •
    impact of environmental regulations and pressures on oil supply on the cost of crude oil, gasoline, diesel and diesel engines;

    •
    future supply, demand, use and prices of crude oil and natural gas and fossil and alternative fuels, including gasoline, diesel, natural gas, biodiesel, ethanol, electricity, and hydrogen;

    •
    estimated incremental costs, annual fuel usage, fuel costs, and annual fuel cost savings for vehicles using natural gas instead of gasoline or diesel;

    •
    projected capital expenditures, project development costs and related funding requirements;

    •
    estimated costs to cover the possible increased price of natural gas above the inherent prices embedded in our customers' fixed price contracts;

    •
    access to equity capital and debt financing options, including, but not limited to, equipment financing, sale of convertible promissory notes or commercial bank financing;

    •
    the impact and availability of federal tax credits and incentives on our business and stock price;

    •
    the impact of advancements in other alternative vehicle fuels and technologies and existing technologies on our business;

    •
    the potential for oil companies, natural gas utilities and others to enter the natural gas fuel market;

    •
    expectations regarding the sale of our interest in our Peruvian joint venture;

    •
    the potential for a single large shareholder to exert significant influence over our corporate decisions; and

    •
    our expectations regarding our natural gas futures contracts, our margin account and our cash balances.

        The preceding list is not intended to be an exhaustive list of all of our forward-looking statements. Although the forward-looking statements in this annual report on Form 10-K reflect our good faith judgment, based on currently available information, they involve known and unknown risks, uncertainties and other factors that may cause our actual results or our industry's actual results, levels of activity, performance, or achievements to be materially different from any future results, levels of activity, performance, or achievements expressed or implied by these forward-looking statements. Factors that might cause or contribute to such differences include, but are not limited to, those discussed in the "Risk Factors" contained in this annual report on Form 10-K. As a result of these factors, we cannot assure you that the forward-looking statements in this annual report on Form 10-K will prove to be accurate. Except as required by law, we undertake no obligation to update publicly any forward-looking statements for any reason after the date we file this annual report on Form 10-K with the Securities and Exchange Commission, or to conform these statements to actual results or to changes in our expectations. You should, however, review the factors and risks we describe in the reports we will file from time to time with the Securities and Exchange Commission after the date we file this annual report on Form 10-K.

        Unless the context indicates otherwise, all references to "Clean Energy," the "Company," "we," "us," or "our" in this annual report on Form 10-K refer to Clean Energy Fuels Corp., together with its majority and wholly owned subsidiaries.

3


 PART I

Item 1.    Business.

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 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 sell non-lubricated natural gas compressors and related equipment used in CNG stations and LNG stations, convert light and medium duty vehicles to run on natural gas, provide design and engineering services for natural gas engine systems, and produce renewable natural gas ("RNG"), which can be used as vehicle fuel or be sold for renewable power generation. In addition, we help our customers acquire and finance natural gas vehicles and obtain local, state and federal grants. CNG and LNG are cheaper than gasoline and diesel fuel, and 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. 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 2012. We believe we are positioned to capture a substantial share of the 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.

        We sell natural gas vehicle fuels in the form of both CNG and LNG. CNG is generally used in automobiles, light to medium-duty vehicles, refuse trucks, and transit buses as an alternative to gasoline and diesel. CNG is produced from natural gas that is supplied by local utilities to CNG vehicle fueling stations, where it is compressed and dispensed into vehicles in gaseous form. We also provide CNG by delivering and vaporizing LNG to turn liquefied natural gas into compressed natural gas ("LCNG"), at locations where no gas pipeline service exists or gas pipeline pressures are inadequate. LNG is generally used in trucks and other medium to heavy duty vehicles as an alternative to diesel, where a vehicle must carry a greater amount of fuel energy than can be feasibly provided onboard by CNG. 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 64 tanker trailers. At the stations, LNG is stored in above ground tanks until dispensed into vehicles in liquid form. We are also beginning to sell RNG (which can be compressed and dispensed as CNG or liquefied and dispensed as LNG) for use as a vehicle fuel.

        We serve fleet vehicle operators in a variety of markets, including trucking, airports, taxis, refuse hauling and public transit. We believe these fleet markets will continue to present a high growth opportunity for natural gas vehicle fuels. At December 31, 2012, we served approximately 650 fleet customers operating approximately 30,600 natural gas vehicles, and we owned, operated or supplied 348 natural gas fueling stations in 32 states, in British Columbia and Ontario within Canada, as well as in Peru.

        We are building a nationwide network of LNG truck fueling stations, which we refer to as America's Natural Gas Highway or ANGH, on the interstate highway system and in major metropolitan areas to serve trucks that are moving goods around the country on natural gas. We expect America's Natural Gas Highway to enable freight trucking coast to coast and border to border within the 48 continental states. We anticipate that America's Natural Gas Highway will initially include approximately 150 truck fueling stations, of which 70 ANGH stations were completed at the end of 2012. Of these 70 stations, seven are open and selling LNG, and the remainder are planned to open as natural gas trucks are deployed in the geographic areas where the stations are located. We expect to

4

build approximately 50 - 70 additional ANGH stations in 2013, depending upon the deployment of natural gas trucks, demand for LNG, and our ability to identify and obtain suitable locations for LNG stations, among other things. Many ANGH stations are located at Pilot Flying J Travel Centers, one of the largest truck fueling operators in the U.S., with approximately 500 truck travel centers in 43 states.

        In November 2012, we entered a strategic collaboration with General Electric ("GE") that we expect to expand the infrastructure for natural gas transportation in the United States by supporting our efforts to build America's Natural Gas Highway. As part of the strategic collaboration, GE is providing us a $200 million credit facility to finance our anticipated purchase of two LNG plants (the "GE Plants") from GE Oil & Gas, Inc., an affiliate of GE that will also be responsible for all engineering, procurement and construction relating to the GE Plants. The strategic collaboration will help ensure that we control a reliable LNG supply for our fueling stations, which will be critical as the long-haul trucking industry transitions to natural gas. The GE partnership is one of the most significant strategic milestones in our history.

        During the past decade, various federal and state air quality and alternative fuel regulations and incentive programs have gone into effect. These regulations have created demand for tradable credits we generate by selling natural gas and RNG for use as a vehicle fuel. These tradable credits include Renewable Identification Numbers ("RINs") that can be generated under the federal Renewable Fuel Standard Phase 2 ("RFS"), which was implemented by the U.S. Environmental Protection Agency ("EPA") according to the Energy Policy Act of 2005. In addition, we can generate credits (which we refer to as "LCFS Credits") under the California low carbon fuel standard ("LCFS") promulgated by the California Air Resources Board ("CARB") pursuant to AB 32—the Global Warming Solutions Act of 2006. In 2012, we recognized $2.9 million of revenue through the sale of LCFS Credits and entered an agreement, which we believe is the first of its kind, to sell RINs to a third party over a three year term with minimum pricing set for the RINs. We believe demand for tradable credits generated under federal and state regulations will grow, and we believe our extensive natural gas fueling infrastructure and our access to LNG and RNG uniquely position us to generate and sell RINs and LCFS Credits.

The Market for Vehicle Fuels

        According to the EIA's Annual Energy Outlook 2013 Early Release (December 5, 2012), the U.S. consumed an estimated 168 billion gasoline gallon equivalents of gasoline and diesel in 2011. Gasoline and diesel comprise the bulk of vehicle fuel consumed in the United States, while CNG, LNG and other alternative fuels, including ethanol, propane, hydrogen, biodiesel, electricity and methanol, represent approximately 3% of consumption, according to the EIA. The Annual Energy Outlook 2013 Early Release projects that natural gas use in the heavy-duty transportation sector will grow to 1.7 trillion cubic feet, or over 12 billion diesel equivalent gallons, by 2040.

        Since 2009, as world economic growth has resumed and political instability has swept the Middle East, oil, gasoline, and diesel prices have been volatile and generally increased, with prices for a barrel of crude often topping $100.

        Higher oil, gasoline and diesel prices improve the magnitude of the immediate market opportunity for natural gas fuels. Increasingly stringent federal, state and local air quality regulations, a desire to lower greenhouse gas emissions, and regulations mandating low carbon fuels continue to develop, which support natural gas fueling options. In addition, the desire for fuel diversity among fleet operators further enhances the market opportunity for natural gas fuels. Internationally, natural gas as an alternative fuel has been widely used for many years. The December 2012 edition of the Gas Vehicles Report estimates that there are only 112,000 natural gas vehicles in the United States, compared to approximately 16.5 million worldwide.

5

Natural Gas as an Alternative Fuel for Vehicles

        We believe that natural gas is an attractive alternative to gasoline and diesel for vehicle fuel in the United States and Canada because it is cheaper and cleaner than gasoline or diesel. In addition, almost all natural gas consumed in the United States and Canada is produced from U.S. and Canadian sources. According to the EIA, in 2011, there were approximately 263 million gasoline gallon equivalents of natural gas consumed in the United States for vehicle use, which is more than double the amount consumed in 2000. The December 2012 Natural Gas Vehicle Report published by the NGV Journal estimates that there are approximately 1,035 natural gas fueling stations in the United States.

Benefits of Natural Gas Fuel

        Less Expensive.    Based on EIA data, since 2004, CNG and LNG have been significantly less expensive than gasoline and diesel. For example, in 2012, the average retail CNG price we charged in California, our most significant market, was $1.18 less per gasoline gallon equivalent than the average California regular unleaded gasoline price of $4.03 per gallon. In addition, CNG and LNG are also currently cheaper than the three other most widely available alternative fuels, propane, ethanol blends and biodiesel, as reported by the Department of Energy on an energy equivalent basis. LNG prices per diesel gallon equivalent are also favorable to diesel prices. In California, for example, Low Sulfur Diesel for 2012 averaged $4.23 per gallon, compared to our LNG diesel gallon equivalent price of $2.91.

        In 2007, new federal emissions requirements became effective for medium and heavy duty engines, and more stringent requirements went into effect in 2010. These requirements limit the levels of specified emissions from new vehicle engines manufactured in or after these years, and have resulted in cost increases for both acquiring and operating diesel vehicles. In order to comply with these standards, 2010 and later diesel engine models have employed significant new emissions control technologies such as advanced particulate matter traps, exhaust gas recirculation systems, and selective catalytic reduction strategies that require urea, all of which have resulted in increases to the cost of medium and heavy duty diesel vehicles. According to industry sources, the purchase price of a 2010 heavy duty diesel vehicle that meets the 2010 diesel emission standards increased by more than $10,000 per vehicle. The 2010 and newer diesel vehicles require the use of ultra-low sulfur diesel fuel to meet the standards, which we believe increases the cost of operating and maintaining medium and heavy duty diesel vehicles. We expect these additional emission requirements will generally increase the cost to own and operate diesel vehicles.

        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, due to high crude oil prices and plentiful domestic supplies of natural gas. In addition, we believe that more stringent emissions requirements will continue to increase the cost of diesel engines and thereby make natural gas vehicles an attractive alternative.

        The chart below shows our average pump prices in California for CNG and LNG relative to California retail regular gasoline and diesel prices on a gasoline gallon equivalent basis for the periods indicated. CNG and LNG powered vehicles produce roughly the same miles per gallon as compared to gasoline or diesel powered vehicles.

6

Average California Retail Prices

        (per gasoline gallon equivalent)(1)

 
   Year Ended December 31,  
 
   2010   2011   2012  

California retail gasoline(2)

   $ 3.09   $ 3.82   $ 4.03  

California retail diesel(2)(3)

   $ 2.84   $ 3.67   $ 3.80  

California CNG—Clean Energy

   $ 2.51   $ 2.70   $ 2.85  

CNG discount to gasoline

   $ (0.58 ) $ (1.12 ) $ (1.18 )

CNG discount to diesel

   $ (0.33 ) $ (0.97 ) $ (0.96 )

California LNG—Clean Energy

   $ 2.03   $ 2.33   $ 2.62  

LNG discount to diesel

   $ (0.81 ) $ (1.34 ) $ (1.19 )
(1)
Industry analysts typically use the gasoline gallon equivalent method in an effort to provide a normalized or "apples to apples" comparison of the relative cost of CNG and LNG compared to gasoline and diesel. Using this method, the cost of CNG and LNG is presented based on the amount of CNG and LNG required to generate the same amount of energy, measured in British Thermal Units, or BTUs, as a gallon of gasoline. Diesel prices were also converted to the energy equivalent of a gallon of gasoline.

(2)
Retail gasoline and diesel prices from the EIA.

(3)
Converted to gasoline gallon equivalents assuming 125,000 BTU and 139,000 BTU per gallon of gasoline and diesel, respectively.

        The following chart shows the estimated annual fuel cost savings that may be achieved by the natural gas vehicle.


Representative Annual per Vehicle Fuel Cost Savings
by Fleet Market for California
Based on Average Fuel Prices During 2012

Market
  Fuel   Estimated annual fuel usage (gallons)(1)(2)   Cost of fuel CNG or
LNG vs. gasoline or
diesel (gallons)(1)(3) 		  Estimated annual fuel cost savings  

Taxi

   CNG or Gasoline     5,000     $2.85(4)     vs. $4.03(4)   $ 5,900  

Shuttle van

   CNG or Gasoline     7,500     $2.85(4)     vs. $4.03(4)   $ 8,850  

Municipal transit bus (CNG)

   CNG or Diesel     16,680     $1.70(5)     vs. $3.14(6)   $ 24,019  

Refuse truck (CNG)

   CNG or Diesel     11,120     $1.54(5)(7)     vs. $3.80(6)   $ 25,131  

Municipal transit Bus (LNG)

   LNG or Diesel     16,680     $1.36(5)     vs. $3.14(6)   $ 29,690  

Refuse truck (LNG)

   LNG or Diesel     11,120     $1.48(5)(7)     vs. $3.80(6)   $ 25,798  

Heavy-duty truck (LNG)

   LNG or Diesel     22,240     $2.62(8)     vs. $3.80(6)   $ 26,243  
(1)
CNG and LNG volumes are stated on a gasoline gallon equivalent basis. Industry analysts typically use the gasoline gallon equivalent method in an effort to provide a normalized or "apples to apples" comparison of the relative cost of CNG and LNG compared to gasoline and diesel. Using this method, the cost of each fuel is presented based on the same amount of energy, measured in BTUs, as a gallon of gasoline.

(2)
Average fleet vehicle usage estimated by us based on experience with our customers. Estimated usage for a taxi is based on a "single-shift" driving program.

7

(3)
Fuel prices for municipal transit buses are lower compared to refuse trucks because fuel for municipal buses is not subject to fuel excise taxes.

(4)
CNG retail pricing is based on average Clean Energy retail station pricing in California during 2012. Gasoline retail pricing is based on California average retail gasoline prices during 2012 as reported by EIA.

(5)
CNG and LNG prices based on average prices paid by representative Clean Energy California fleet customers in 2012.

(6)
Diesel price based on EIA reported average diesel price in California in 2012.

(7)
Excludes California Board of Equalization taxes of $0.0875 per gasoline gallon equivalent on CNG vehicles and $0.06 per gallon on LNG vehicles, as these customers typically buy an annual permit of $168.00 per truck over 12,000 gross vehicle weight that allows them to opt out of this tax.

(8)
LNG retail price is based on average Clean Energy retail station pricing at the Port of Long Beach station in 2012.

        Cleaner.    Use of CNG and LNG as a vehicle fuel creates less pollution than use of gasoline or diesel, based on data from South Coast Air Quality Management District studies. On-road mobile source emissions reductions are becoming increasingly important because many urban areas have failed to meet federal air quality standards. This failure has led to the need for more stringent governmental air pollution control regulations.

        Transportation is responsible for approximately 27% of total U.S. greenhouse-gas emissions, and over 13% of global greenhouse gas emissions. Under the LCFS, CARB recognizes that the "well to wheels" analysis of natural gas as a vehicle fuel indicates that natural gas provides an up to 29% reduction in greenhouse gas emissions for light duty vehicles and up to a 23% reduction for medium and heavy-duty vehicles.

        RNG use is also a means to reduce greenhouse gas emissions. RNG is produced from waste streams such as landfills, animal waste digesters and waste water treatment plants. RNG can be liquefied or injected into a pipeline and is compatible with existing natural gas fueling infrastructure. A full lifecycle analysis performed by CARB has determined that use of RNG generated from landfills as a vehicle fuel can reduce greenhouse gas emissions by up to 88% as compared to gasoline. Further, the RFS creates tradable credits, or RINs, that can be generated by production and use of RNG in the transportation sector and can be sold to fuel providers that are not compliant under the RFS. RNG can also be used to generate renewable power in gas-fired power generation units.

        We sell RNG we produce for use as a vehicle fuel through our extensive natural gas fueling infrastructure. In addition, we sell the RINs and LCFS Credits that we generate through these transactions. We plan to escalate our activities in this area by using our fueling infrastructure to sell increasing amounts of RNG, as well as by entering additional transactions to sell the LCFS Credits and RINs we generate. We have also agreed to market and sell RNG produced by third parties and retain a portion of the RIN and LCFS Credit values generated from those transactions.

        Safety.    As reported by NGV America, CNG and LNG are safer than gasoline and diesel because they dissipate into the air when spilled or in the event of a vehicle accident. When released, CNG and LNG are also less combustible than gasoline or diesel because they ignite only at relatively higher temperatures. The fuel tanks and systems used in natural gas vehicles are subjected to a number of federally required safety tests, such as fire, environmental hazard tests, burst pressures, and crash testing, according to the U.S. Department of Transportation National Highway Traffic Safety Administration. CNG and LNG are stored in above ground tanks and therefore cannot contaminate soil or groundwater.

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        Domestic and plentiful supply.    In 2012, the U.S. consumed 18.6 million barrels of crude oil per day, of which 51% was supplied from the U.S. and Canada and 49% was imported from other countries, according to the EIA. By comparison, the EIA estimates that over 99% of the natural gas consumed in the United States in 2012 was supplied from the United States and Canada making it less vulnerable to foreign supply disruption. In addition, the EIA estimates that less than 0.15% of the estimated 25.3 trillion cubic feet of natural gas consumed in the U.S. in 2012 was used for vehicle fuel.

        Analysts believe that there is a significant worldwide supply of natural gas relative to crude oil. According to the 2012 BP Statistical Review of World Energy, on a global basis, the ratio of proven natural gas reserves to 2011 natural gas production was 17% greater than the ratio of proven crude oil reserves to 2011 crude oil production. This analysis suggests significantly greater long-term availability of natural gas than crude oil based on current consumption.

        On April 27, 2011, the Potential Gas Committee ("PGC") released its report on the natural gas resource base in the U.S. The report states that the U.S. possesses a total resource base of 1,898 trillion cubic feet ("Tcf"). This is the highest resource evaluation in the PGC's 45 year history. Another study, published by Navigant Consulting in March 2012, defined the recoverable natural gas resources at 2,543 Tcf, or more than 100 years at current consumption levels.

        A 2010 IHS CERA special report "Fueling America's Energy Future" stated "North American discovered natural gas resources have increased by more than 1,800 Tcf over the prior three years, bringing the total natural gas resource base to more than 3,000 Tcf, a level that could supply current consumption for well over 100 years."

        In addition, the final 2012 Annual Energy Outlook report from the EIA estimates that shale gas could represent 49% (13.6 Tcf) of U.S. natural gas production by the year 2035, up from the 14% and 23% (5 Tcf) of domestic natural gas produced in 2009 and 2010, respectively. The EIA estimates that, based upon 2010 consumption levels, there is enough available shale gas to satisfy demand for the next 100 years. The primary reason for the availability of additional natural gas is the increased successful use of recent shale drilling technology and continued drilling in shale plays with high concentrations of natural gas liquids and crude oil, which have a higher energy value than dry natural gas.

        Hydraulic fracturing (commonly called "fracking" or "hydrofracking") is a technique in which water, sand and a small amount of chemicals are pumped into the well to unlock the hydrocarbons trapped in shale formations by opening cracks (fractures) in the rock and allowing natural gas to flow from the shale into the well. When used in conjunction with horizontal drilling, hydraulic fracturing enables gas producers to extract shale gas at a reasonable cost. Horizontal drilling is an enhanced oil recovery or gas recovery method. A horizontal well is commonly defined as any well in which the lower part of the well bore parallels the oil zone. The benefits of horizontal wells include the avoidance of drawdown-related problems such as water/gas coning, and extension of wells by means of multiple drain holes. Without these techniques, natural gas does not flow to the well rapidly, and commercial quantities cannot be produced from shale because the natural gas would not flow from the formation at high enough rates to justify the cost of drilling. There have been recent efforts to place new regulatory requirements on the production of natural gas by hydraulic fracturing, and any regulations that make it more expensive or unprofitable to produce natural gas through hydraulic fracturing could lead to reduced natural gas supply and increased natural gas prices.

Natural Gas Vehicles and Engines

        Natural gas vehicles use internal combustion engines similar to those used in gasoline or diesel powered vehicles. A natural gas vehicle uses sealed storage cylinders to hold CNG or LNG, specially designed fuel lines to deliver natural gas to the engine, and an engine tuned to run on natural gas. Natural gas fuels have higher octane content than gasoline or diesel, and the acceleration and other performance characteristics of natural gas vehicles are similar to those of gasoline or diesel powered

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vehicles of the same weight and engine class. Natural gas vehicles, whether they run on CNG or LNG, are refueled using a hose and nozzle that makes an airtight seal with the vehicle's gas tank. For heavy duty vehicles, spark ignited natural gas vehicles generally operate more quietly than diesel powered vehicles. Natural gas vehicles typically cost more than gasoline or diesel powered vehicles, primarily due to the higher cost of the storage systems that hold the CNG or LNG.

        Any passenger car, truck, bus or other vehicle is capable of being manufactured or modified to run on natural gas. Outside the U.S., numerous makes and models of vehicles are factory produced to run on natural gas as bi-fuel vehicles or in some cases as dedicated natural gas vehicles. In the U.S., however, a limited number of models of natural gas engines and vehicles have been historically available. We believe that in the near-term new heavy-duty natural gas engines and trucks will be offered by most, if not all, original equipment manufacturers. We further expect that additional models of other natural gas vehicles will continue to become available as natural gas is increasingly adopted as a vehicle fuel in the U.S.

        In the U.S., there are currently a limited number of factory built natural gas passenger and light-duty vehicles. Honda offers the Civic NG, a 4-door passenger sedan; General Motors Company ("GM") offers a light-duty Chevy Express/GMC Savana cargo van; and The Vehicle Production Group has in the past, and may again in the future, offer the MV-1, a wheelchair accessible sedan that uses a Ford Motor Company ("Ford") engine and chasis. Chrysler Group, LLC and GM also offer bi-fuel pickup trucks. Bi-fuel vehicles can run on either natural gas or gasoline and have tanks for each fuel. A limited number of other dedicated (uses only natural gas fuel) and bi-fuel passenger vehicles, vans and light duty trucks are available through small volume manufacturers, such as our wholly-owned subsidiary, BAF Technologies, Inc. ("BAF"). These small volume manufacturers offer model vehicles made by major automobile manufacturers that have been modified to use natural gas and certified to meet federal and state emissions and safety standards. Several GM and Ford models are now available from these manufacturers, including the Ford Transit Connect, Ford E Series vehicles, Ford F Series trucks, and GM vehicles that include pickups and vans. We anticipate additional models through various outlets will become available in 2013. Modifications for dedicated natural gas vehicles involve removing the gasoline fuel system and replacing it with a compressed natural gas fuel storage system and reflashing the engine's computer controlled fuel management system.

        There are two natural gas engines available for the over-the-road ("OTR") trucking market at this time:

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    8.9 liter spark-ignited engine with 250-320 horsepower and 660-1,000 lb-ft torque produced by Cummins Westport, Inc. ("CWI"), a joint venture of Cummins, Inc. and Westport Innovations, Inc. This engine is used in commercial trucks, refuse trucks and buses, and has been the backbone for natural gas trucking to date.

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    15 liter high pressure direct injection engine with 400-450 horsepower and 1,800 lb-ft torque produced by Westport Innovations, Inc., which requires the use of a diesel particulate filter and selective catalytic reduction with urea injection to reduce emissions in compliance with EPA 2010 standards. This engine is finding use in applications that require high horsepower, such as transporting loads in excess of the 80,000 pound U.S. federal highway standard and up steep inclines.

        Every major truck original equipment manufacturer ("OEM"), including Freightliner, Navistar, International, Kenworth, Peterbilt and Volvo, offers natural gas trucks using the engines described above. Further, other vehicle OEMs offer natural gas school buses, shuttles, transit buses and street sweepers.

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New Heavy Duty Truck Engines and Building America's Natural Gas Highway

        Based on our experience, the natural gas engines available for the trucking market are not well suited to serve the U.S. heavy-duty OTR trucking market. We believe the preferred engine for this market is an approximately 12 to 13 liter engine that delivers up to 400 horsepower and 1,400 to 1,500 lb-ft torque. In contrast, the 8.9 liter engine delivers inadequate horsepower and torque, and the 15 liter engine is too large and expensive to efficiently transport the loads typically hauled by U.S. carriers, and has the added complication of requiring three fuels—LNG, diesel and urea. We believe the lack of an engine that is well-suited for the U.S. heavy-duty OTR truck market has hampered the adoption of natural gas fuel by this market.

        The first natural gas truck engine that we believe is well-suited for the U.S. heavy-duty OTR trucking market, a CWI spark-ignited 11.9 liter engine that delivers 350 - 400 horsepower and 1,400 lb-ft torque, is expected to be commercially available by the second calendar quarter of 2013. CWI has been field testing this engine since mid-2012, and we anticipate that the engine will be well-received by heavy-duty truck operators. In addition, Volvo is developing a 13 liter engine that is expected to be available in 2014, and Cummins is developing a new 15 liter spark ignited engine that it plans to sell in 2015. Major truck OEMs, including Freightliner, International, Navistar, Kenworth, Peterbilt, Autocar and Volvo, plan to offer natural gas trucks using these engines.

        We anticipate the commercial roll-out of these and other natural gas engines that are well-suited for the U.S. heavy-duty OTR trucking market, together with the economic and environmental benefits of natural gas fuel, will result in increased adoption of natural gas fueled trucks by the U.S. heavy-duty OTR trucking industry. Heavy duty trucks are generally high volume users of vehicle fuel. We believe many use 20,000 diesel gallons or more per truck per year, and the lower cost of natural gas compared to diesel will result in substantial fuel savings for the operator. With over eight million heavy-duty trucks registered in the U.S., we believe this market has the potential to become our largest.

        As these engines are adopted and increasing numbers of heavy-duty natural gas trucks are deployed in the U.S., natural gas fueling infrastructure must be available to serve the needs of truck operators. To meet these needs, we are building America's Natural Gas Highway, a nationwide network of LNG truck fueling stations on the interstate highway system and in major metropolitan areas. We expect America's Natural Gas Highway to initially include approximately 150 truck fueling stations, of which 70 ANGH stations were completed at the end of 2012. Of these 70 stations, seven are open and selling LNG, and the remainder are planned to open as natural gas engines that are well-suited for the trucking market (including the CWI 11.9 liter engine) become available and trucks powered by such engines are deployed in the geographic areas where the stations are located. We expect to build approximately 50 - 70 additional ANGH stations in 2013, depending upon the deployment of natural gas trucks, demand for LNG, and our ability to identify and obtain suitable locations for LNG stations, among other things. Many ANGH stations are located at Pilot Flying J Travel Centers, one of the largest truck fueling operators in the U.S., with approximately 500 truck travel centers in 43 states.

Products and Services

        We sell CNG and LNG and provide operating and maintenance ("O&M"), services to our customers. For the year ended December 31, 2012, CNG and RNG (together) represented 72% and LNG represented 28% of our natural gas sales (on a gasoline gallon equivalent basis). We design and construct CNG, LNG and LCNG fueling stations and sell or lease some of those stations to our customers. We also sell RNG produced by our subsidiary Clean Energy Renewable Fuels, LLC ("CERF"), sell natural gas vehicles produced by our subsidiary BAF, provide design and engineering services for natural gas engine systems, and sell non-lubricated natural gas fueling compressors and related equipment and maintenance services through our subsidiary Clean Energy Compression Corp,

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also known as I.M.W. Industries Ltd. ("IMW"). In addition, we help our customers acquire and finance natural gas vehicles. We also generate and sell RINs and LCFS Credits.

        CNG Sales.    We sell CNG through fueling 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 brokers under standard, floating-rate arrangements and then compress and dispense it into our customers' vehicles. Our CNG 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 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 a small amount of CNG under fixed-price contracts. Our customers typically are billed monthly based on the volume of CNG sold at a station. The remainder of our CNG sales are on a per fill-up basis at prices we set at the pump based on prevailing market conditions. These customers typically pay using a credit card at the station.

        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, which we call the Pickens Plant and the Boron Plant, respectively. The Pickens Plant has the capacity to produce 35 million gallons of LNG per year and includes tanker trailer loading facilities and a 1.0 million gallon storage tank that can hold up to 840,000 usable gallons. The Boron Plant is capable of producing 60 million gallons of LNG per year and has tanker trailer loading facilities similar to the Pickens Plant and a 1.8 million gallon storage tank that can hold up to 1.5 million usable gallons.

        We expect that we will need to secure additional sources of LNG for America's Natural Gas Highway. Therefore, we plan to expand the Boron Plant to increase its production capacity to 90 million gallons of LNG per year. Further, we plan to build the GE Plants, and anticipate that such plants will be completed and commence LNG production in 2015. We expect that the GE Plants will each be initially capable of producing up to 90 million gallons of LNG per year, and they will each be designed to expand their production capability to up to 365 million gallons of LNG per year. We also believe additional LNG production plants will need to be built by our company or third parties.

        We sell LNG to fleet customers, who typically own and operate their fueling stations. Increasingly, we also sell LNG to fleet and other customers at our public-access LNG stations. During 2012, we procured 44% of our LNG from third-party producers, and we produced the remainder of the LNG at the Pickens and Boron Plants. We expect to enter into additional purchase contracts with third party LNG producers. For LNG that we purchase from third parties, we have entered into, and we may enter into additional, "take or pay" contracts that require us to purchase minimum volumes of LNG at index-based rates.

        We deliver LNG via our fleet of 64 tanker trailers to fueling stations, where it is stored and dispensed in liquid form into vehicles. We typically own the tanker trailers and we contract with third parties to provide tractors and drivers. Each LNG tanker trailer is capable of carrying 10,000 gallons of LNG. To optimize our distribution network, we use an automated tracking system that enables us to monitor the location of a tanker trailer at any time, as well as an automated fueling station tank-monitoring system that enables us to efficiently schedule the refilling of each station, which helps ensure that our customers have sufficient fuel to operate their fleets. We also anticipate that we will need to purchase or lease additional tanker trailers to transport LNG to ANGH stations, and that we will need to increase the number of third parties who provide us contract carrier services. We sell LNG principally through supply contracts that are priced on either a fixed-price or index-plus basis. LNG sales based on an index-plus methodology increase or decrease as a result of an increase or decrease in the price of natural gas. Our LNG contracts provide that we charge our customers periodically based on the volume of LNG supplied. We also sell LNG on a per fill-up basis at prices we set at the pump based on prevailing market conditions. These customers typically pay using a credit card at the station.

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        Operation and Maintenance.    We perform O&M services for CNG stations, which are either owned by us or our customers. In addition, we perform O&M services for LNG stations we own, and we perform O&M services for a small number of LNG stations owned by our customers and supplied by us. Most of the CNG and LNG stations that we maintain or supply are monitored from our centralized operations center, facilitating increased reliability and safety, as well as lower operating costs. This monitoring helps us to ensure the timely delivery of fuel and to respond rapidly to any technical difficulties that may arise. In addition, we have an automated billing system that enables us to track our customers' usage and bill them efficiently. As of December 31, 2012, we had an operations team of 109 employees, including 67 full-time employees dedicated to performing preventative maintenance and available to respond to service requests in 32 states and in Canada. In addition, we have 74 full-time employees dedicated to performing preventative maintenance on IMW's foreign installations in Bangladesh, Colombia, Peru and China.

        Our Station Network.    As of December 31, 2012, we owned, operated or supplied 348 fueling stations for our customers in 32 states and Canada. We owned 166 of the stations, and our customers owned the other 182 stations.

        Station Construction and Engineering.    Since 2008, we have built 212 natural gas fueling stations, either serving as general contractor or supervising qualified third-party contractors, for ourselves or our customers. We acquired the additional stations we own that we did not build through acquisition of assets or businesses. We use a combination of custom designed and off-the-shelf equipment to build fueling stations. Equipment for a CNG station typically consists of dryers, compressors, dispensers and storage tanks (which hold a relatively small buffer amount of compressed natural gas). Equipment for an LNG station typically consists of storage tanks that hold 5,000 to 25,000 gallons of LNG, plus related dispensing equipment.

        A number of our fueling stations have separate public access areas for retail customers, which have the look, feel and dispensing rates of a traditional gasoline fueling station. Our CNG dispensers are designed to fuel up to six gasoline gallon equivalents per minute, which is comparable to a traditional gasoline fueling dispenser. Our LNG dispensers are designed to fuel up to 20 diesel gallon equivalents per minute, similar to a diesel fueling dispenser. LNG dispensing requires special training and protective clothing (gloves and safety glasses) because of the extreme low temperatures of LNG.

        To enhance our station construction capabilities, in 2010, we acquired Wyoming Northstar Incorporated, ("Northstar") a leading provider of LNG and LCNG station design, construction operations and maintenance services. Northstar is also a leader in LNG and LCNG fueling system technologies, including manufacturing one of only two weights-and-measures certified LNG dispensers. Northstar is a key component of our plan to roll-out America's Natural Gas Highway.

        RNG.    We own a 70% interest in a RNG production facility at the McCommas Bluff landfill located in Dallas, Texas. We sell RNG produced at the facility to Shell Energy North America under a Gas Sale Agreement and, depending upon RNG production volumes, we have the ability to sell RNG produced by the facility as a vehicle fuel. We own a second RNG production facility located at a Republic Services landfill in Canton, Michigan. This facility was completed in December 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 (the effectiveness of such contract is subject to the California Energy Commission ("CEC") certifying the facility). We are building a third RNG facility at a Republic Services landfill in North Shelby, Tennessee, and we expect the facility to be operational during the first quarter of 2014. We are seeking to expand our RNG business by pursuing additional RNG production projects. We sell some of the RNG we currently produce, and expect to sell a significant amount of the RNG we produce at the facilities we are building and plan to build, through our natural gas fueling infrastructure for use as a vehicle fuel. In addition, we plan to purchase RNG from third party producers, and sell that RNG for vehicle use through our fueling infrastructure.

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        Vehicle conversions.    Our subsidiary, BAF, provides natural gas conversions, alternative fuel systems, application engineering, service and warranty support, and research and development for natural gas vehicles. BAF is headquartered in Dallas, Texas and is a Ford Qualified Vehicle Modifier for all Ford natural gas products. Due to the limited number of factory built natural gas passenger and light-duty vehicles, we believe it is strategically important to own a company that produces vehicles that can fuel at our natural gas stations. To further enhance the capabilities of BAF, we acquired a 100% interest in ServoTech Engineering, Inc. ("ServoTech"), a company that provides design and engineering services for natural gas engine systems. ServoTech also provides emission reduction systems for manufacturing applications.

        Natural gas fueling compressors.    Our IMW subsidiary manufactures and services non-lubricated natural gas fueling compressors and related equipment. IMW is headquartered near Vancouver, British Columbia, has additional manufacturing facilities near Shanghai, China, and in Ferndale, Washington, and has sales and service offices in Bangladesh, Colombia, Peru and the United States. We believe IMW gives us several strategic advantages. First, it enables us to satisfy our internal compressor needs, since compressors are the most important piece of equipment for a CNG station. As the adoption of natural gas vehicles has increased, our CNG station construction backlog has increased and our compressor requirements have increased. We believe our compressor needs will continue to grow in the future. Second, IMW enables us to provide certain customers with a "factory direct" offering. Since some customers do not want our full suite of services and simply want a station that they can own and operate, we can offer them a high quality and low cost "equipment only" solution. Third, IMW allows us to participate in the global growth of natural gas vehicle fueling. IMW has a strong reputation in the global market, and we believe IMW will benefit and participate in such growth.

        Vehicle Acquisition and Finance.    We offer vehicle finance services for some of our customers' purchases of natural gas vehicles or the conversion of their existing gasoline or diesel powered vehicles to operate on natural gas. We loan to certain qualifying customers a portion of, and on occasion up to 100% of, the purchase price of their natural gas vehicles. We may also lease vehicles in the future. 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.

        VETC.    Since October 1, 2006, we have received a federal fuel tax credit ("VETC") of $0.50 per gasoline gallon equivalent of CNG and $0.50 per liquid gallon of LNG that we sell as vehicle fuel. Based on the service relationship with our customers, either we or our customers were able to claim the credit. The program providing for the VETC expires on December 31, 2013.

        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 RINs when we sell RNG for use as a vehicle fuel. We can sell these RINs and LCFS Credits to third parties who need the RINs and the LCFS Credits to comply with federal and state requirements. In 2012, we realized $2.9 million in revenue through the sale of LCFS Credits. We anticipate that we will generate and sell increasing numbers of RINs and LCFS Credits as we grow our business and sell increasing amounts of CNG, LNG and RNG for use as a vehicle fuel.

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Sales and Marketing

        We have sales representatives in all of our major operating territories, including Los Angeles, San Francisco, San Diego, Phoenix, Boston, New York, Denver, Dallas, Atlanta, New Jersey, Pennsylvania, Seattle, New Mexico, Chicago, Ohio, Florida, Virginia, Minnesota, Kentucky, Indiana, New Hampshire, Tennessee, and Missouri in the U.S., in Toronto and Vancouver, Canada and in Bangladesh, Colombia, Peru and China. At December 31, 2012, we had 115 employees in sales and marketing, including seven employees of BAF and 18 employees of IMW. As our business grows and we enter new markets over the next several years, we intend to continue expanding our sales and marketing team, primarily by adding specialized sales experts to focus on opportunities in targeted metropolitan areas and in locations where we have existing fueling infrastructure. We market primarily through our direct sales force, attendance at trade shows and participation in industry conferences and events. Our sales and marketing group works closely with federal, state and local government agencies to educate them on the value of natural gas as a vehicle fuel and to keep abreast of proposed and newly adopted regulations that affect the industry.

Key Markets and Customers

        At December 31, 2012, we had 650 fleet customers operating approximately 30,600 vehicles, including approximately 6,600 transit buses, 2,700 taxis, 2,300 shuttles, 5,200 refuse trucks and 1,400 heavy-duty trucks. We target customers in a variety of markets, such as trucking, airports, taxis, refuse, public transit and government fleets. During 2010, 2011 and 2012, approximately 30%, 21% and 33% of our revenues, respectively, were derived from contracts with governmental entities such as municipal transit fleets. We do not depend on a single customer or a few customers, the loss of which would have a material adverse effect on us.

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    Trucking—Many shippers, manufacturers, retailers and other truck fleet operators have begun adopting natural gas fueled trucks to move their freight. Some of the national fleets piloting heavy-duty tractors with natural gas are among the largest fleets in the world including Con-way, FedEx, Frito-Lay, Ruan, Ryder, Schneider, Swift, UPS, Werner and YRC Worldwide. Interest by shippers also increased in 2012 as several Fortune 100 companies entered into discussions with their carrier base about the use, or expansion of use, of natural gas trucks in their fleets. We anticipate that the continued commercial roll-out of heavy-duty natural gas engines that are well-suited for the U.S. OTR trucking market will result in increased adoption of natural gas fueled trucks by the U.S. trucking industry. Heavy-duty trucks in the U.S. are generally high volume users of vehicle fuel. We believe many use 20,000 diesel gallons or more per truck per year, and the lower cost of natural gas compared to diesel will result in substantial fuel savings for the operator. With over eight million heavy-duty trucks registered in the U.S. market, we believe this market has the potential to become our largest. As a result, we are making a significant commitment of capital and resources to construct America's Natural Gas Highway, a network of LNG fueling stations intended to serve OTR and regional heavy-duty natural gas trucks that are responsible for America's goods movement.

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    Airports—Many U.S. airports face emissions challenges and are under regulatory directives and political pressure to reduce pollution, particularly as part of any expansion plans. Many of these airports already have adopted various strategies to address tailpipe emissions, including rental car and hotel shuttle consolidation. In order to reduce emissions levels further, many airports require or encourage service vehicle operators to switch their fleets to natural gas, including airport delivery fleets, door-to-door and parking shuttles and taxis. To assist in this effort, airports are contracting with service providers to design, build and operate natural gas fueling stations in strategic locations on their property. Airports we serve include Albuquerque, Atlanta Hartsfield Jackson International, Austin Bergstrom International, Baltimore Washington

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      International, Burbank, Cleveland Hopkins International, Dallas-Ft. Worth International, Denver International, George Bush International (Houston), Hartford, Las Vegas, Love Field (Dallas), Long Beach, LaGuardia (New York), Los Angeles International, New Orleans, Newark International, Oakland International, Ontario, Palm Springs, Philadelphia International, Phoenix Sky Harbor International, San Francisco International, Santa Ana/John Wayne, San Diego International, SeaTac International (Seattle), Tampa International, Tucson International and Will Rogers (Oklahoma City). At these airports, our representative customers include taxi and van fleets, as well as parking and car rental shuttles. We believe these are well suited customers because they use a relatively high volume of vehicle fuel and can be served by centralized fueling infrastructure.

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    Taxis—According to the Taxi, Limousine, and Paratransit Association, there were approximately 6,300 companies operating 171,000 taxicabs in the United States in 2010. We believe that less than 2% of these vehicles are natural gas vehicles. Because taxi fleets travel many miles, use a relatively high volume of vehicle fuel and can refuel at a central location, we believe they are excellent candidates to use CNG. Natural gas vehicles provide taxi fleets a convenient way to reduce operating costs and provide a clean environment for their drivers and customers. We serve approximately 2,100 taxis in Southern California, the San Francisco Bay Area, Dallas, Houston, Las Vegas, New York City, Phoenix, Tucson and Seattle. We have also seen a significant interest in new policy initiatives at major airports across the country this past year, including the Philadelphia, Cincinnati, and Newark Airports.

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    Refuse Haulers—According to INFORM, there are nearly 200,000 refuse trucks in the United States, consuming approximately two billion gallons of fuel per year, that collect and haul refuse and recyclables from collection points to landfills, transfer stations, waste-to-energy facilities, and material recovery facilities. Due to the desire to recognize operating savings, and to address their customers' demands to reduce emissions, refuse haulers are increasingly adopting trucks that run on CNG. We estimate that out of the approximately 8,000 new refuse collection trucks ordered during 2012, nearly 3,000 were powered by CNG fuel. Waste Management has made public its commitment that 85% of its new vehicle orders in 2013 will be natural gas vehicles. Further, Republic Services has committed that 65% of its new purchases in 2013 will be natural gas vehicles and 40% of their fleet will be CNG within five years. We serve numerous Waste Management and Republic Services sites now, and hope to expand this number in the future. In addition to Waste Management and Republic Services, we also have contracts with private waste haulers such as Blue Diamond Disposal (NJ), Burrtec (CA), Central Jersey Waste, Choice Waste (FL), CleanScapes (Seattle), Garofalo V & Sons (NY), Homewood Disposal (IL), Mission Trail (CA), Livermore Sanitation (CA), USA Recycling (CT), Peoria Disposal (IL), Progressive Waste (LA), Recology (Formerly Norcal Waste), South San Francisco Scavenger and Waste Pro (FL), among others. We also provide vehicle fueling services to municipal refuse fleets including fleets in Burbank, Dallas, Fresno, Los Angeles, Sacramento, San Antonio, and on Long Island, New York among other locations. We believe refuse companies are ideal customers because they can be served by centralized fueling infrastructure and they use a relatively high volume of fuel. We currently serve 101 hauling companies.

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    Transit agencies—According to the American Public Transportation Association, there are over 66,200 municipal transit buses operating in the United States. In many areas, increasingly stringent emissions standards have limited the fueling options available to public transit operators. Transit agencies typically fuel at a central location and they use high volumes of fuel. As a result, transit agencies have been early adopters of natural gas vehicles, with almost 36% of all buses in the United States operating on LNG or CNG, according to the American Public Transportation Agency 2012 Public Transportation Factbook. Our representative public transit customers include Boston Metropolitan Transit Development Agency, City of Elk Grove

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      (California), City of Laredo Transit (Texas), City of Montebello (California), Dallas Area Rapid Transit, Foothill Transit (California), Long Beach Transit (California), Los Angeles Metropolitan Transit Authority, Orange County Transit Authority, Phoenix Transit, Tempe Transit, Regional Transit Commission of Nevada, Regional Transit Authority (Ohio), Santa Cruz Metropolitan, Santa Monica Big Blue Bus, Stark Area Regional Transit Authority (SARTA) of Ohio and Tulsa Transit (Oklahoma).

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    Government fleets—According to the Federal Highway Administration, or FHA, in 2010, there were over 4.6 million government fleet vehicles in operation in the United States, including those operated by federal, state and municipal entities. In California and Texas, for example, according to the FHA, there were over 636,000 and 532,000 government vehicles, respectively. As government regulations on pollution continue to become more stringent, government agencies are evaluating ways to make their fleets cleaner and run more economically. Under the federal Energy Policy Act of 1992, 75% of new light-duty vehicles purchased by federal fleet operators are required to run on alternative fuels. Our representative government fleet customers include the California Department of Transportation (Los Angeles and Orange County), State of New York, City of Denver, City and County of Los Angeles, City of San Antonio, Town of Smithtown (NY), City and County of San Francisco, City and County of Dallas and City of Phoenix.

Acquisitions

        In August 2008, we acquired a 70% interest in a facility that collects, processes and sells RNG collected from a landfill in Dallas, Texas. On October 1, 2009, we completed our acquisition of BAF, and on September 7, 2010, we acquired the advanced, non-lubricated natural gas fueling compressor and related equipment manufacturing and servicing business of IMW. On December 15, 2010, we acquired Northstar, and in 2011 and 2012, we acquired the natural gas fueling infrastructure construction business of Weaver Electric, Inc., and ServoTech, respectively. In the future, we anticipate pursuing acquisitions and partnerships as we become aware of opportunities where we believe we can increase our competitive advantages, expand our product offerings, or enhance our market position.

Tax Incentives

        U.S. federal and state government tax incentives and grant programs continue to be available to reduce the cost of acquiring and operating a natural gas vehicle fleet. Incentives may include funds to offset the cost of acquiring natural gas vehicles or converting vehicles to use natural gas, constructing natural gas fueling stations or selling CNG or LNG.

Grant programs

        We apply for and help our fleet customers apply for federal, state and regional grant programs in states where we operate including California, Connecticut, Georgia, Idaho, Indiana, Nevada, New Jersey, New York, Ohio, Pennsylvania, and Texas. These programs provide funding for natural gas vehicle purchases and station construction.

Competition

        The market for vehicular fuels is highly competitive. The biggest competition for CNG and LNG is gasoline and diesel, and many of the producers and sellers of these fuels are large entities that have significantly greater resources than we have. The vast majority of vehicles in the United States and Canada are powered by gasoline or diesel.

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        A significant number of established businesses, including oil and gas companies, fuel providers, vehicle OEMs, refuse collectors, natural gas utilities, industrial gas companies and other organizations have entered or are planning to enter the market for natural gas vehicle fuels. Many of these current and potential competitors have substantially greater financial, marketing, research and other resources than we have. We also compete with suppliers of other alternative vehicle fuels, including ethanol, biodiesel and hydrogen fuels, as well as providers of hybrid and electric vehicles. Some of our current principal competitors in the market for natural gas vehicle fuels include:

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    Intergrys, a provider of CNG fuel infrastructure and fueling services through its subsidiaries Trillium USA and Pinnacle CNG, which it acquired in 2011;

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    Gas producers Encana, Chesapeake and Apache, who are investing in CNG fueling infrastructure;

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    Mansfield Oil, a diesel fuel provider to fleets that recently acquired a California-based fuel infrastructure company;

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    TruStar Energy (formerly Vocational Energy), a fueling infrastructure company focused on the refuse market;

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    Shell Oil Products U.S., which has announced plans to construct and operate a network of natural gas fueling stations at TravelCenters of America locations in the U.S.;

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    Blu LNG, a company that owns LNG fueling stations in Utah and has announced plans to develop a national network of LNG fueling stations; and

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    Applied LNG Technology and Prometheus Energy, each of which distributes LNG in the western United States.

        Several natural gas utilities, including Pacific Gas and Electric, operate public access CNG stations that compete with our stations. In December 2012, the California Public Utilities Commission approved a compression services tariff application by the Southern California Gas Company, allowing the utility to offer natural gas fueling infrastructure construction services that compete with our offerings. In addition, utilities in several states, including Michigan, Illinois, New Jersey, North Carolina, Missouri, and Georgia, have made efforts to invest in the market for natural gas vehicle fuels.

        We sell CNG fueling equipment through our IMW subsidiary. The market for CNG fueling equipment is highly competitive with several competitors selling in multiple countries. We believe our competitors for CNG fueling equipment include Aspro, GNC Galileo, GE, SAFE, ANGI Energy Systems, Inc., and Atlas Copco. Numerous other equipment or compressor manufacturing companies may also enter the market in the future. We also compete with many third parties for the rights to develop RNG production facilities, as well as for customers to purchase the RNG we produce.

        We own, operate or supply 348 CNG and LNG fueling stations. We operate 281 CNG fueling stations, which we estimate is approximately four times the number of CNG fueling stations operated by our next largest competitor. We believe we are the only company in the U. S. or Canada that provides both CNG and LNG on a significant scale, and we operate in more states and provinces than any of our competitors. We expect, however, competition to intensify in the near term as the use of natural gas vehicles and the demand for natural gas vehicle fuel and related equipment increases. Increased competition will lead to amplified pricing pressure, reduced operating margins and fewer expansion opportunities.

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Background on Clean Air Regulation

        Federal Clean Air Act—The Federal Clean Air Act provides a comprehensive framework for air quality regulation in the United States. Many of the federal, state and local air pollution control programs regulating vehicles and stationary sources have their basis in Title I or Title II of the Federal Clean Air Act.

        Title I of the Federal Clean Air Act charges the EPA with establishing uniform National Ambient Air Quality Standards for criteria air pollutants anticipated to endanger public health and welfare. States in turn have the primary responsibility under the Federal Clean Air Act for achieving these standards. If any area within a state fails to meet these standards for a criteria air pollutant, the state must develop an implementation plan and local agencies must develop air quality management plans for achieving these standards. Many state programs regulating stationary source emissions, vehicle pollution or mobile sources of pollution are developed as part of a state implementation plan. For mobile sources, two criteria pollutants in particular are of concern: ozone and particulate matter. As components of state implementation plans, individual states have also adopted diesel fuel standards intended to reduce NOx and particulate matter emissions. Texas and California have both adopted low-NOx diesel programs. Additionally, many state implementation plans and some quality management plans include vehicle fleet requirements specifying the use of low emission or alternative fuels in government vehicles.

        Title II of the Federal Clean Air Act authorizes the EPA to establish emission standards for vehicles and engines. Diesel fueled heavy duty trucks and buses have recently accounted for substantial portions of NOx and particulate matter emissions from mobile sources, and diesel emissions have received significant attention from environmental groups and state agencies. In 2001, the EPA finalized its Heavy Duty Highway Rule, also known as the 2007 Highway Rule. The 2007 Highway Rule seeks to limit emissions from diesel fueled trucks and buses on two fronts: new tailpipe standards requiring significantly reduced NOx and particulate matter emissions for new heavy duty diesel engines, and new standards requiring refiners to produce low sulfur diesel fuels that will enable more extensive use of advanced pollution control technologies on diesel engines.

        The 2007 Highway Rule's tailpipe standards apply to new diesel engines. Specifically, new particulate matter standards took effect in the model year 2007 and new NOx standards were phased in between 2007 and 2010. The rule's fuel standards call for a shift by U.S. refiners and importers from low sulfur diesel, with a sulfur content of 500 parts per million (ppm), to ultra low sulfur diesel, with a sulfur content of 15 ppm. The rule, which will effect a transition to ultra low sulfur diesel, required refiners to begin producing ultra low sulfur diesel fuels on June 1, 2006.

        Although the majority of state air pollution control regulations are components of state implementation plans developed pursuant to Title I of the Federal Clean Air Act, states are not precluded from developing their own air pollution control programs under state law. For example, the California Air Resources Board and the South Coast Air Quality Management District have promulgated a series of airborne toxic control measures under California state law, several of which are directed toward reducing emissions from diesel fueled engines.

        Although the federal government has not adopted any laws that comprehensively regulate greenhouse gas emissions, the EPA is developing regulations that would regulate these pollutants under the Clean Air Act.

        Federal RFS.    In February 2010, the EPA finalized the RFS, which creates RINs that can be generated by production and use of RNG in the transportation sector and can be sold to fuel providers that are not compliant under the RFS.

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        California's AB 32—In September 2006, California Governor Arnold Schwarzenegger signed AB 32—the Global Warming Solutions Act of 2006—into law, which calls for a cap on greenhouse-gas emissions throughout California and a statewide reduction to 1990 levels by the year 2020, and an additional 80% reduction below 1990 levels by 2050. To achieve the state's greenhouse gas reductions for mobile sources, CARB, in 2009, approved the LCFS, which requires a 10% carbon reduction in gasoline and diesel fuels sold in the State of California by 2020, and therefore encourages other low carbon "compliant" transportation fuels (including CNG, LNG and RNG) to enter the marketplace by allowing them to generate LCFS Credits that can be sold to noncompliant regulated parties.

Government Regulation and Environmental Matters

        Certain aspects of our operations are subject to regulation under federal, state, local and foreign laws. If we were to violate these laws or if the laws or enforcement proceedings were to change, it could have a material adverse effect on our business, financial condition and results of operations.

        Regulations that significantly impact our operations are described below.

    •
    CNG and LNG stations—To construct a CNG or LNG fueling station, we must obtain a facility permit from the local fire department and either we or a third party contractor must be licensed as a general engineering contractor. The installation of each CNG and LNG fueling station must be in accordance with federal, state and local regulations pertaining to station design, environmental health, accidental release prevention, above-ground storage tanks, hazardous waste and hazardous materials. We are also required to register with certain state agencies as a retailer/wholesaler of CNG and LNG.

    •
    Transfer of LNG—Federal Safety Standards require each transfer of LNG to be conducted in accordance with specific written safety procedures. These procedures must be located at each place of transfer and must include provisions for personnel to be in constant attendance during all LNG transfer operations.

    •
    LNG liquefaction plants—To build and operate LNG liquefaction plants, we must apply for facility permits or licenses to address many factors, including storm water and wastewater discharges, waste handling and air emissions related to production activities or equipment operations. The construction of LNG plants must also be approved by local planning boards and fire departments.

    •
    Financing—State agencies generally require the registration of finance lenders. For example, in California, pursuant to the California Finance Lenders Law, one of our subsidiaries is a registered finance lender with the California Department of Corporations.

    •
    Vehicle conversion—Vehicles that are converted to run on natural gas and sold by BAF are subject to EPA emission requirements and certifications, federal vehicle safety regulations and, in some cases, such as California, state emission requirements and certifications.

    •
    Natural gas fueling compressors—CNG fueling equipment is manufactured to meet the electrical and mechanical design standards of the country where the equipment will be installed. Our manufacturing facility in Canada is registered with the British Columbia Safety Authority and the Society of Mechanical Engineers for manufacturing and operating pressure vessels.

    •
    RNG—Our RNG production facilities are required to comply with Title V air permits. In addition, our RNG projects must produce RNG that meets the gas quality specifications of the local utilities that accept the gas. These specifications are approved by the relevant state utilities commission. In California, the gas utilities pipeline specifications prohibit the injection of landfill gas. If the gas utilities that we rely upon to accept and ship our RNG product adopt new gas

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      specifications or otherwise refuse to accept our RNG product, we will be unable to sell the product and generate revenues.

        We believe we are in substantial compliance with environmental laws and regulations and other known regulatory requirements. Compliance with these regulations has not had a material effect on our capital expenditures, earnings or competitive position. More stringent environmental laws and regulations may be imposed in the future, such as more rigorous air emissions requirements or proposals to make waste materials subject to more stringent and costly handling, disposal and clean-up requirements and regulations of greenhouse gas emissions from our LNG plants or stations. Accordingly, new laws or regulations or amendments to existing laws or regulations might require us to undertake significant capital expenditures, which may have a material adverse effect on our business, consolidated financial condition, results of operations and cash flows.

Employees

        As of December 31, 2012, we employed 1,038 people, of whom 115 were in sales and marketing, 779 were in operations, engineering and vehicle and compressor production, and 144 were in finance and administration. We have not experienced any work stoppages and none of our employees is subject to collective bargaining agreements. We believe that our employee relations are good.

Financial Information about Segments and Geographic Areas

        We operate our business in one reportable segment. For information about our revenues from external customers, operating income (loss) and long-lived assets broken down by geographic area, see note 14 to our consolidated financial statements.

Additional Information

        Our web site is located at www.cleanenergyfuels.com. We make available free of charge on our web site our annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports filed pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended, as soon as reasonably practicable after we electronically file such material with, or furnish it to, the Securities and Exchange Commission. The reference to our website is intended to be an inactive textual reference and the contents of our website are not intended to be incorporated into this report.

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 annual report on Form 10-K 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. In that case, the trading price of our common stock could 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.

        In 2010, 2011 and 2012, we incurred pre-tax losses of $4.2 million, $48.2 million, and $99.6 million, respectively. Our loss for 2010 was decreased by a derivative gain of $10.3 million on our Series I warrants (see notes 10 and 18 of the consolidated financial statements); our loss for 2011 includes a $2.7 million derivative gain; and our loss for 2012 includes a $3.4 million derivative gain. During 2010

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and 2011, our losses were substantially decreased by our receipt of approximately $16.0 million and $17.9 million of revenue from federal fuel tax credits, respectively. The program under which we received such credits expired on December 31, 2011; however, the American Taxpayer Relief Act (which was signed into law on January 2, 2013) reinstated such program retroactive to January 1, 2012 and extended it through December 31, 2013. We estimate that for 2012 we will receive $20.8 million of revenue from the federal fuel tax credits, which will be recognized during the first quarter of 2013. To build our business and improve our financial performance, we must continue to invest in developing the natural gas vehicle fuel market and offer our customers competitively priced natural gas vehicle fuel and other products and services. If we do not achieve or maintain profitability that can be sustained in the absence of federal fuel tax credits and other government incentive programs, our business will suffer and the price of our common stock may drop. In addition, if the price of our common stock increases during future periods when our Series I warrants are outstanding, we may be required to recognize material losses based on the valuation of the outstanding Series I warrants.

A material portion of our historical revenues are associated with a federal fuel excise tax credit.

        In 2010 and 2011, we recorded approximately $16.0 million and $17.9 million of revenue, respectively, related to fuel tax credits, representing approximately 7.6% and 6.1%, respectively, of our total revenue during those periods. Further, we expect to receive $20.8 million of revenue related to fuel tax credits for 2012. In addition, on July 15, 2010, the IRS sent us a letter disallowing approximately $5.1 million related to certain excise tax credit claims that we made from October 1, 2006 to June 30, 2008. After negotiations with the IRS and the other impacted parties, we settled this claim with the IRS for $2.1 million.

If commercial introduction of the CWI 11.9 liter engine is further delayed, or if the engine is not adopted by truck operators as we anticipate, our results of operations and business prospects will be adversely affected.

        We believe that our entry into the heavy duty truck market, and the execution of our ANGH initiative, depends upon the successful launch of the CWI 11.9 liter engine (or a comparable engine that we believe would be well-suited for the U.S. heavy-duty OTR trucking market). The launch of this engine has been previously delayed and may be further delayed, and we have no control over when the engine will become commercially available. Further, if the CWI 11.9 liter engine becomes commercially available, it may not be adopted and deployed by heavy-duty truck operators in sufficient numbers to justify building America's Natural Gas Highway. Heavy-duty trucks powered by the engine will cost more, as compared to comparable diesel trucks, and may experience operational or performance issues. If the CWI 11.9 liter engine does not become commercially available or if meaningful numbers of the engine are not deployed, our business and financial results could be harmed.

The failure of our initiative to build America's Natural Gas Highway would materially and adversely affect our financial results and business.

        We are building America's Natural Gas Highway, a network of LNG truck fueling stations on interstate highways and in major metropolitan areas. Building America's Natural Gas Highway requires a significant commitment of capital and other resources, and our ability to successfully execute our plan faces substantial risks, including:

    •
    We have no influence over when natural gas trucks powered by engines that are well-suited for the United States heavy duty truck market (including the Cummins-Westport 11.9 liter engine) will become commercially available, or whether such availability is delayed;

    •
    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 identify and obtain sufficient rights to use suitable locations for ANGH stations;

    •
    Further, development of America's Natural Gas Highway will require substantial additional amounts of capital, which may not be available on terms favorable to us or at all;

    •
    We may experience delays in building stations, including delays in obtaining necessary permits and approvals;

    •
    We will need to construct a significant number of fueling stations in 2013, and we may not be able to hire and retain the necessary qualified personnel, and our operational infrastructure and systems may be inadequate;

    •
    We complete ANGH stations before there are sufficient numbers of customers who are capable of fueling at the stations, and if such customers do not materialize, we will have substantial investments in assets that do not produce revenues and we may lose money on LNG fuel that is supplied to the ANGH stations but is not purchased by customers;

    •
    We may not be able to acquire and transport sufficient volumes of LNG to meet the needs of customers fueling at ANGH stations;

    •
    LNG may not be the fuel of choice for the United States heavy-duty truck market; and

    •
    Building ANGH imposes significant added responsibilities on our management team and will divert their attention from other areas of our business.

        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. Failure to successfully execute our ANGH initiative will materially and adversely affect our financial results, operations and business, and our ability to repay our debt.

Automobile and engine manufacturers currently produce very few originally manufactured natural gas vehicles and engines for the United States and Canadian markets, which may restrict our sales of CNG, LNG and RNG.

        Limited availability of natural gas vehicles and engine sizes restricts their wide scale introduction and narrows our potential customer base. Original equipment manufacturers produce a small number of natural gas engines and vehicles in the U.S. and Canadian markets, and they may not make adequate investments to expand their natural gas engine and vehicle product lines. The technology used in some of the heavy duty vehicles that run on LNG is also relatively new and has not been previously deployed or used in large numbers of vehicles. Natural gas vehicles may require servicing and further technology refinements to address performance issues that may occur as vehicles are deployed in large numbers and are operated under strenuous conditions. If heavy duty LNG truck purchasers are not satisfied with truck performance, additional heavy-duty truck engine manufacturers do not enter the market for LNG engines, or LNG engines are not otherwise developed, produced and adopted in greater numbers, our ANGH investments and LNG fueling business may be significantly impaired, which would adversely affect our financial performance. Due to the limited supply of natural gas vehicles, our ability to promote natural gas vehicles and our natural gas fuel sales will be restricted.

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

        We will be required to raise debt or equity capital to fund the growth of our business. At December 31, 2012, we had total cash and cash equivalents of $108.5 million, short-term investments of $38.2 million and $13.2 million in restricted cash for capital use. Our business plan for 2013 calls for

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approximately $186.2 million in capital expenditures. We may also require capital for unanticipated expenses, mergers and acquisitions and strategic investments. In addition, we have committed to significant future payments that we will be required to make in connection with our acquisitions of IMW and Northstar. At December 31, 2012, our future payments for IMW and Northstar totaled $25.1 million and $4.1 million, respectively. Our IMW future payment obligations are in the form of promissory notes, and such notes are secured by IMW's assets. As a result, if we do not make scheduled IMW future payments, the party to whom such payments are due may be entitled to accelerate the maturity of the notes and exercise other remedies available to a secured creditor. We are also obligated to pay up to $40.0 million as additional consideration related to our IMW acquisition if IMW meets certain performance measurements.

        Equity or debt financing options may not be available on terms favorable to us or at all. Additional sales of our common stock or securities convertible into our common stock will dilute existing stockholders and may result in a decline in our stock price. We may also pursue debt financing options including, but not limited to, equipment financing, the sale of convertible notes, asset based loans, project finance debt, 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. If we are unable to obtain debt or equity financing in amounts sufficient to fund any unanticipated expenses, capital expenditures, mergers, acquisitions or strategic investments, we will be forced to suspend or curtail these capital expenditures or postpone or delay potential acquisitions or other strategic transactions, which would harm our business, results of operations, and future prospects.

We are required to make substantial payments to the holders of our convertible notes.

        At December 31, 2012, we had an aggregate of $249.0 million of convertible notes outstanding (such convertible notes were issued in July 2011, August 2011, and July 2012). In addition, we have agreed to issue an additional $50.0 million of convertible notes in June 2013. All such convertible notes bear interest at the rate of 7.5% per annum. The $50.0 million outstanding principal amount of convertible notes we issued in July 2011 is due and payable in July 2018; the $149.0 million outstanding principal amount of convertible notes we issued in August 2011 is due and payable in August 2016; and the $50.0 million outstanding principal amount of convertible notes we issued in July 2012 is due and payable in July 2019. We may repay the convertible notes in common stock or cash. We expect our interest payment obligations under the convertible notes to be approximately $20.7 million for the year ending December 31, 2013 (such amount includes the interest that will be due on an additional $50.0 million of convertible notes we anticipate issuing in June 2013). In future periods, we may not have sufficient capital resources to enable us to fulfill our payment obligations to the holders of our convertible notes. If we are unable to make scheduled payments or comply with the other provisions of the agreements relating to the convertible notes, the holders of such convertible notes may be permitted under certain circumstances to accelerate the maturity of the convertible notes and exercise other remedies provided for in the notes and under applicable law. An acceleration of the maturity of the convertible notes that is not rescinded will have a material adverse effect on our company.

We may encounter difficulties building the GE Plants and such facilities may never be completed. If we commence construction of either GE Plant we will need to comply with significant obligations to GE.

        Our ability to commence construction of the GE Plants will depend on a number of conditions, including the availability of sites upon which to construct the GE Plants and 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, 2014, GE's obligation to fund the GE Plants will terminate. This may result in us not being able to satisfy our LNG supply needs, and may adversely affect us.

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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. 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 plants. The GE Plants may cost more than we expect, and we may not be able to pay the additional cost. If the GE Plants are completed, they may not generate enough cash flow to pay our obligations to GE because they may not operate correctly or we may not be able to sell enough of the LNG the plants produce. If we do not fulfill our obligations, we may lose all of our investments in the GE plants, GE may take over ownership of the GE plants, and GE may sue us for damages.

If the prices of CNG and LNG do not remain sufficiently below the prices of gasoline and diesel, potential customers will have less incentive to purchase natural gas vehicles, which would decrease demand for CNG and LNG and reduce our growth.

        Natural gas vehicles cost more than comparable gasoline or diesel powered vehicles because the components needed for a vehicle to use natural gas adds to a vehicle's base cost. If the prices of CNG and LNG do not remain sufficiently below the prices of gasoline or diesel, operators may be unable to recover the additional costs of acquiring or converting to natural gas vehicles in a timely manner, and they may choose not to use natural gas vehicles. Our ability to offer CNG and LNG fuel to our customers at lower prices than gasoline and diesel depends in part on natural gas prices remaining lower, on an energy equivalent basis, than oil prices. If the price of oil, gasoline and diesel declines, it will make it more difficult for us to offer our customers discounted prices for CNG and LNG as compared to gasoline and diesel prices and maintain an acceptable margin on our sales. Recent and significant volatility in oil and gasoline prices demonstrate that it is difficult to predict future transportation fuel costs. In addition, any new regulations imposed on natural gas extraction in the United States, particularly on extraction of natural gas from shale formations, could increase the costs of domestic gas production or make it more costly to produce natural gas in the United States, which could lead to substantial increases in the price of natural gas. Reduced prices for gasoline and diesel fuel may cause potential customers to delay or reject converting their fleets to run on natural gas. In that event, our sales of natural gas fuel and vehicles would be slowed and our business would suffer.

The volatility of natural gas prices could adversely impact the adoption of CNG and LNG vehicle fuel and our business.

        In the recent past, the price of natural gas has been volatile, and this volatility may continue. Increased natural gas prices affect the cost to us of natural gas and will adversely impact our operating margins in cases where we have committed to sell natural gas at a fixed price without an effective futures contract in place that fully mitigates the price risk or where we otherwise cannot pass the increased costs on to our customers. In addition, higher natural gas prices may cause CNG and LNG to cost as much as or more than gasoline and diesel generally, which would adversely impact the adoption of CNG and LNG as a vehicle fuel and consequently our business. Conversely, lower natural gas prices reduce our revenues due to the fact that in a significant number of our customer agreements, the commodity cost is passed through to the customer. Among the factors that can cause fluctuations in natural gas prices are changes in domestic and foreign supplies of natural gas, domestic storage levels, crude oil prices, the price difference between crude oil and natural gas, price and availability of alternative fuels, weather conditions, negative publicity surrounding drilling techniques, level of consumer demand, economic conditions, price of foreign natural gas imports, and domestic and foreign governmental regulations and political conditions. In particular, there have been recent efforts to place new regulatory requirements on the production of natural gas by hydraulic fracturing of shale gas reservoirs. Hydraulic fracturing of shale gas reservoirs 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

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expensive or unprofitable to produce natural gas through hydraulic fracturing could lead to increased natural gas prices.

Our growth is influenced by government incentives and mandates for clean burning fuels and alternative fuel vehicles. The failure to pass new legislation with incentive programs may adversely affect our business.

        Our business is influenced by federal, state and local government tax credits, rebates, grants and similar 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. Some government programs and incentives have recently expired, such as the federal income tax credit that was available to offset 50% to 80% of the incremental cost of purchasing new or converted natural gas vehicles, and the absence of these programs and incentives could have a detrimental effect on the natural gas vehicle and fueling industry, including sales at our wholly owned subsidiary, BAF. If expired incentives are not reinstated or extended, or if new incentives are not passed, fewer natural gas vehicles may be sold and used and our revenue and financial performance may be adversely affected. Furthermore, the failure of proposed federal, state or local government incentives which promote the use of natural gas and RNG as a vehicle fuel to pass into law could result in a negative perception by the market generally and a decline in the market price of our common stock. 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 II, would adversely affect our business and ability to sell RNG we produce at a profit. In addition, if grant funds are no longer available under government programs for the purchase and construction of natural gas vehicles and stations, the purchase of natural gas vehicles and station construction could slow and our business and results of operations may be adversely affected. Reduction in tax revenues associated with high unemployment rates or economic recession or slow-down could result in a significant reduction in funds available for government grants that support vehicle conversion and station construction, which could impair our ability to grow our business.

Our growth depends in part on environmental regulations and programs mandating the use of cleaner burning fuels, and modification or repeal of these regulations may adversely impact our business.

        Our business depends in part on environmental regulations and programs in the United States that promote or mandate the use of cleaner burning fuels, including natural gas and RNG for vehicles. Industry participants with a vested interest in gasoline and diesel, many of which have substantially greater resources than we do, invest significant time and money in an effort to influence environmental regulations in ways that delay or repeal requirements for cleaner vehicle emissions. Further, economic difficulties may result in the delay, amendment or waiver of environmental regulations due to the perception that they impose increased costs on the transportation industry that cannot be absorbed in a challenging economy. The delay, repeal or modification of federal or state regulations or programs that encourage the use of cleaner vehicles could also have a detrimental effect on the United States natural gas vehicle industry, which, in turn, could slow our growth and adversely affect our business.

The use of natural gas as a vehicle fuel may not become sufficiently accepted for us to expand our business.

        To expand our business, we must develop new customers and sell increasing amounts of CNG, LNG and RNG, which we may not be able to do. Whether we will be able to expand our customer base will depend on a number of factors, including the level of acceptance and availability of natural gas vehicles, the growth in our target markets of fueling station infrastructure that supports CNG and LNG sales, our ability to supply CNG and LNG at competitive prices and acceptance of our technology, fuel systems and services. A decline in oil, diesel fuel and gasoline prices may result in decreased interest in alternative fuels like CNG and LNG. Further, potential customers may not find our product or service offerings acceptable.

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We face increasing competition from oil and gas companies, fuel providers, refuse companies, industrial gas companies, natural gas utilities, and other organizations that have far greater resources and brand awareness than we have.

        A significant number of established businesses, including oil and gas companies, refuse collectors, natural gas utilities and their affiliates, industrial gas companies, station owners, fuel providers and other organizations have entered or are planning to enter the natural gas fuels market. For example, in 2012, Shell Oil Products U.S. publicized its plans to construct and operate a network of natural gas fueling stations at TravelCenters of America locations in the United States. Many of these current and potential competitors have substantially greater financial, marketing, research and other resources than we have. Natural gas utilities, particularly in California, continue to own and operate natural gas fueling stations that compete with our stations, and in December 2012, the California Public Utilities Commission approved a compression services tariff application by the Southern California Gas Company, allowing the utility to offer natural gas fueling infrastructure construction services that compete with our offerings. In addition, utilities in several states, including Michigan, Illinois, New Jersey, North Carolina and Georgia, have made efforts to invest in the natural gas vehicle fuel space. We expect competition to intensify in the near term in the market for natural gas vehicle fuel as the use of natural gas vehicles and the demand for natural gas vehicle fuel increases. Increased competition will lead to amplified pricing pressure, reduced operating margins and fewer expansion opportunities. To compete effectively in this environment, we must continually develop and market new and enhanced product offerings at competitive prices and must have the resources available to invest in the further development of our business. Our failure to compete successfully would adversely affect our business and financial results.

Our global operations expose us to additional risk and uncertainties.

        We have operations in a number of countries, including the United States, Canada, China, Colombia, Bangladesh and Peru. Our 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 herein, our global operations may be subject to risks and uncertainties that may limit our ability to operate our business, including:

    •
    compliance with the United States Foreign Corrupt Practices Act;

    •
    political unrest, terrorism and economic and financial instability;

    •
    unexpected changes in regulatory requirements and uncertainty related to developing legal and regulatory systems governing economic and business activities, real property ownership and application of contract rights;

    •
    import-export regulations;

    •
    difficulties in enforcing agreements and collecting receivables;

    •
    difficulties in ensuring compliance with the laws and regulations of multiple jurisdictions;

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

    •
    changes in labor practices, including wage inflation, labor unrest and unionization policies;

    •
    limited intellectual property protection;

    •
    longer payment cycles by international customers;

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    •
    currency exchange fluctuations;

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

    •
    potentially adverse tax consequences; and

    •
    differing employment practices and labor issues.

        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. We do not engage in currency hedging activities to limit the risks of currency fluctuations.

We may encounter challenges managing our growth, which may divert resources and limit our ability to successfully expand our operations.

        We have been and continue to be engaged in a period of rapid and substantial growth, which places a strain on our operational infrastructure and imposes significant added responsibilities on members of our management. Our ability to manage our operations and growth effectively requires us to hire, train and integrate necessary personnel to further develop our operational, financial and management controls, expand and improve our financial reporting and legal compliance systems, and improve management of our natural gas station construction, maintenance and operations projects. If we are not able to effectively manage our business growth and operations in a cost-effective manner, our operating results, sales and revenues may be negatively impacted.

We depend on key personnel to operate our business, and if we are unable to retain our current personnel or hire additional personnel, 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 relationship with us at any time, and their knowledge of our business and industry would be extremely difficult to replace. If we are unable to attract and retain our executive officers and key employees, our business, operating results and financial condition could be harmed. In addition, our management team has a long history of working together, and we believe that our key executives have developed highly successful and effective working relationships. If one or more of these individuals leave, we may not be able to fully integrate new executives or replicate the current dynamic, which may cause our operations to suffer.

We may not be successful in managing or integrating IMW into our business, which could prevent us from realizing the expected benefits of the acquisition and could adversely affect our future results.

        The integration of IMW into our business presents significant challenges and risks to our business, including (i) the distraction of management from other business concerns, (ii) expansion into foreign markets, (iii) the introduction of IMW's compressor and related equipment manufacturing and servicing business, which is a new product line for us, (iv) achievement of appropriate internal controls over financial reporting and (v) the monitoring of compliance with all laws and regulations. IMW derives significant revenue from sales in emerging markets, and prior to the acquisition, IMW was not required to comply with the United States Foreign Corruption Practices Act or any of the requirements

28

of Sarbanes-Oxley. If we do not successfully integrate IMW into our business and maintain regulatory compliance, we may not realize the benefits expected from the acquisition and our results of operations could be materially adversely affected. If the revenue of IMW declines or grows more slowly than we anticipate, or if its operating expenses are higher than we expect, we may not be able to achieve, sustain or increase the growth of our business, in which case our financial condition will suffer and our stock price could decline.

A significant portion of the purchase price of IMW was allocated to intangibles, including goodwill, and a write-off of all or part of these intangibles, including goodwill could adversely affect our operating results.

        Under business combination accounting standards, we allocated the total purchase price of IMW to its net tangible assets and liabilities and intangible assets based on their fair values as of the date of the acquisition and recorded the excess of the purchase price over those values as goodwill. Our estimates of the fair value of the assets and liabilities of IMW were based upon certain assumptions, including assumptions regarding new business, believed to be reasonable, but which are inherently uncertain. Pursuant to the applicable accounting standards, we initially allocated $126.4 million of the purchase price for IMW to intangibles, including goodwill. Our intangibles, including goodwill, could be impaired if developments affecting the acquired compressor manufacturing operations or the markets in which IMW produces and/or sells compressors lead us to conclude that the cash flows we expect to derive from its manufacturing operations will be substantially reduced. An impairment of all or part of our intangibles, including goodwill, could adversely affect our results of operations.

The failure of one of our subsidiaries to comply with the terms of its bond financing agreements would impair our rights in our Dallas, Texas RNG production facility.

        Dallas Clean Energy McCommas Bluff, LLC ("DCEMB"), in which we indirectly own a 70% interest and which owns and operates our Dallas, Texas RNG production facility, entered into, among other documents, the Loan Agreement, the Note, the Deed of Trust and the Security Agreement, which are defined elsewhere in this report (collectively the "Bond Agreements") in connection with its issuance of certain Revenue Bonds (see note 9 of the consolidated financial statements). Pursuant to the Bond Agreements, DCEMB is subject to certain covenants, including a requirement to make loan repayments on the Revenue Bonds. This repayment obligation is secured by a security interest in all of the Collateral (as defined in the Security Agreement), which includes, but is not limited to, DCEMB's rights, title and interest in any gas sale agreements and the funds and accounts held under an indenture. If DCEMB defaults on its obligation to make loan repayments on the Revenue Bonds, the Issuer or the Trustee (as defined in the Bond Agreements) may, among other things, take whatever action at law or in equity as may be necessary or desirable to ensure loan repayments are made on the Revenue Bonds. If the Issuer or the Trustee take any such actions, or if DCEMB otherwise fails to comply with its covenants and other obligations under the Bond Agreements, our rights in DCEMB would be impaired, and our business and results of operations may be adversely affected.

The infrastructure to support gasoline and diesel consumption is vastly more developed than the infrastructure for natural gas vehicle fuels.

        Gasoline and diesel fueling stations and service infrastructure are widely available in the United States. For natural gas vehicle fuels to achieve more widespread use in the United States and Canada, they will require a promotional and educational effort and the development and supply of more natural gas vehicles and fueling stations. This will require significant continued effort by us, as well as government and clean air groups, and we may face resistance from oil companies and other vehicle fuel companies.

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We have significant contracts with federal, state and local government entities that are subject to unique risks.

        We have existing, and will continue to seek, long-term CNG and LNG station construction, maintenance and fuel sales contracts with various federal, state and local governmental bodies, which accounted for approximately 30%, 21% and 33% of our annual revenues in 2010, 2011 and 2012, respectively. In addition to our 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 appropriations for subsequent performance periods are not made. The termination of funding for a government program supporting any of our CNG or LNG operations could result in a loss of anticipated future revenues attributable to that program, which could have a negative impact on our operations. In addition, government entities with whom 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 have been and may continue to be protracted. In many cases, unsuccessful bidders for government agency contracts are provided the opportunity to formally protest certain contract awards through various agency, 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. We may not be awarded contracts for which we bid, and substantial delays or cancellation of purchases may even follow our successful bids as a result of such protests.

The budget deficits being experienced by many governmental entities may reduce the available funding for certain natural gas programs and services and the purchase of CNG or LNG fuel, which could reduce our revenue and impair our financial performance.

        Many governmental entities are experiencing significant budget deficits, which has and may continue to reduce or curtail their ability to fund natural gas fuel programs, purchase natural gas vehicles or provide public transportation and services, which would harm our business. Furthermore, in response to budget deficits, such governmental entities have and may continue to request or demand that we lower our price for CNG or LNG fuel.

Conversion of light and medium-duty vehicles to run on natural gas is time-consuming and expensive and may limit the growth of our sales.

        Conversion of light and medium-duty vehicle engines from gasoline or diesel to natural gas is performed by only a small number of vehicle conversion suppliers (including our wholly owned subsidiary, BAF) that must meet stringent safety and engine emissions certification standards. The engine certification process is time consuming and expensive and raises vehicle costs. In addition, conversion of vehicle engines from gasoline or diesel to natural gas may result in vehicle performance issues or increased maintenance costs that could discourage our potential customers from purchasing converted vehicles that run on natural gas and impair the financial performance of BAF. Without an increase in vehicle conversion options, and reduced vehicle conversion costs, our sales of natural gas vehicle fuel and converted natural gas vehicles, through BAF, may be restricted and our revenue will be reduced both by less demand for natural gas vehicle fuel and less demand for converted natural gas vehicles.

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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 and our business may suffer.

        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 adoption of natural gas vehicles. Advances in gasoline and diesel engine technology, especially hybrids, 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 increasingly 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 or the perception that electric heavy duty trucks may soon be widely available and provide satisfactory performance in heavy duty applications may reduce demand for heavy duty LNG trucks. In addition, hydrogen and other alternative fuels in experimental or developmental stages may eventually offer a cleaner, more cost-effective alternative to gasoline and diesel than natural gas. Advances in technology that slow the growth of or conversion to natural gas vehicles, or which 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 fuel vehicles.

Our ability to obtain LNG is constrained by fragmented and limited production and increasing competition for LNG supply.

        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 or at all. If LNG liquefaction plants we own, or if any of those from which we purchase LNG, are damaged by severe weather, earthquake or other natural disaster, or otherwise experience prolonged down time, or if we or others do not build additional LNG liquefaction plants, our LNG supply will be restricted. If we are unable to supply enough of our own LNG or purchase it from third parties to meet customer demand, we may be liable to our customers for penalties and lose customers. Competition for LNG supply is escalating. For example, we increasingly compete to purchase LNG with third parties that use LNG to fuel equipment deployed in oil and gas production activities. In addition, the execution of our business plan will require substantial growth in the available LNG supply across the United States, and if this supply is unavailable, it will constrain our ability to increase the market for LNG fuel, including supplying LNG fuel to heavy duty truck customers, and will adversely affect our investments in America's Natural Gas Highway. If we experience an LNG supply interruption or LNG demand that exceeds available supply, or if we have difficulty entering or maintaining relationships with contract carriers to deliver LNG on our behalf, our ability to expand LNG sales to new customers will be limited, our relationships with existing customers may be disrupted, and our results of operations may be adversely affected. 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 on those sales due to our increased transportation costs.

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

        We are a party to two LNG supply agreements that have a take-or-pay commitment, and we may enter into additional take-or-pay commitments, particularly in connection with America's Natural Gas Highway. 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, 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 does not meet our expectations, our operating and supply costs may increase as a percentage of revenue and negatively impact our margins.

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If our futures contracts do not qualify for hedge accounting, our net income (loss) will fluctuate more significantly from quarter to quarter based on fluctuations in the market value of our futures contracts.

        We account for our futures activities under the relevant derivative accounting guidance, which requires us to value our futures contracts at fair market value in our financial statements. At December 31, 2012, all of our futures contracts qualified for hedge accounting. To the extent that all or some of our futures contracts do not qualify for hedge accounting, we could incur significant increases and decreases in our net income (loss) in the future based on fluctuations in the market value of our futures contracts from quarter to quarter. We had no realized derivative gains or losses related to our natural gas futures contracts for the years ended December 31, 2010, 2011 and 2012. Any negative fluctuations may cause our stock price to decline due to our failure to meet or exceed the expectations of securities analysts or investors.

Compliance with potential greenhouse gas regulations affecting our LNG plants or fueling stations 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. Other states and the federal government are considering passing measures to regulate and reduce greenhouse gas emissions. Any of these regulations, when and if implemented, may regulate the greenhouse gas emissions produced by our LNG production plants or our CNG and LNG fueling stations and require that we obtain emissions credits or invest in costly emissions prevention technology. We cannot currently estimate the potential costs associated with federal or state regulation of greenhouse gas emissions from our LNG plants or CNG and LNG stations, and these unknown costs are not contemplated by our customer agreements. These unanticipated costs may have a negative impact on our financial performance and may impair our ability to fulfill customer contracts at an operating profit.

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 and natural disasters, which could result in uncontrollable flows of natural gas, fires, explosions and other damages. For example, operation of LNG pumps requires special training and protective equipment 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. Improper refueling of LNG vehicles can result in venting of methane gas, which is a potent greenhouse gas, and LNG related methane emissions may in the future be regulated by the EPA or by state regulations. Additionally, CNG fuel tanks, if damaged or improperly maintained or installed, may rupture and the contents of the tank may rapidly decompress and result in death or 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. If CNG or LNG vehicles are perceived to be unsafe, it will harm our growth and negatively affect BAF's ability to sell converted CNG vehicles, which would impair our financial performance.

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 in the future. There are risks associated with providing financing or leasing that could cause us to lose money. These risks include the following: (i) the equipment financed consists mostly of vehicles that are mobile and easily damaged, lost or stolen, (ii) the borrower may default on payments, (iii) we may not be able to bill

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properly or track payments in adequate fashion to sustain growth of this service, and (iv) the amount of capital available to us is limited and may not allow us to make loans required by customers. Some of our customers, such as taxi owners, may depend on the CNG vehicles that we finance or lease to them as their sole source of income, which may make it difficult for us to recover the collateral in a bankruptcy proceeding. As of December 31, 2012, we had $7.9 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 business 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, emissions certifications and taxation, among others. These laws and regulations are complex, change frequently and have tended to become more stringent over time. Failure to comply with these 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. From time to time, as part of the regular overall evaluation of our operations, including newly acquired operations, we may be subject to compliance audits by regulatory authorities. In addition, any 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.

        In connection with our operations, we often need facility permits or licenses to address storm water or wastewater discharges, waste handling, and air emissions. This may subject us to permitting conditions that may be onerous or costly. Compliance with laws and regulations and enforcement policies by regulatory agencies could require us to make material expenditures and may distract our officers, directors and employees from the operation of our business.

Our RNG business may not be successful.

        We completed a new RNG production facility in Canton, Michigan in 2012 and we are developing a pipeline quality RNG project near Memphis, Tennessee. We are also in the process of expanding operations at our RNG production facility at the McCommas Bluff landfill outside of Dallas, Texas. In addition, we are seeking to increase our RNG business by pursuing additional projects. RNG production represents a new area of investment and operations for us, and we may not be successful in developing these projects and generating a financial return from our investment. 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 absence of government programs and regulations that support such activities. Our ability to succeed in expanding our McCommas Bluff project and developing other projects depends on our ability to obtain necessary financing, successfully manage the construction and operation of RNG production facilities and our ability to either sell the 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 unsuccessful in obtaining necessary financing or managing the construction and operation of our RNG production facilities, or if we are unable to either sell RNG at a substantial premium to conventional natural gas prices or to sell RINs or other credits we generate at favorable prices, our business and financial results may be materially and adversely affected. In addition, due to recent regulatory and legislative changes in California, our ability to sell RNG produced by projects outside of California to California power plants is limited. If we cannot sell RNG we produce to California power plants for use as a Renewable Portfolio Standard compliant fuel, we may not be able to obtain long-term, fixed premium prices for RNG. In the absence of state and federal programs that support premium prices for RNG, or that

33

allow us to generate and sell RINs and other credits, we will be unable to generate profit and financial return from these investments, and our financial results could be materially and adversely affected.

We may experience difficulties producing RNG.

        Our financial results and operations will be negatively impacted if we experience difficulties producing RNG. Our ability to produce RNG may be adversely affected by a number of factors beyond our control including 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 upgrade or expand our RNG facilities, which may result in plant shutdowns or cause delays that reduce the amount of RNG we produce.

Our quarterly results of operations have not been predictable in the past and have fluctuated significantly and may not be predictable and may fluctuate in the future.

        Our quarterly results of operations have historically experienced significant fluctuations. Our net losses (income) were approximately $24.4 million, $(9.9) million, $1.8 million, $(13.8) million, $9.8 million, $5.6 million, $11.4 million, $20.9 million, $31.9 million, $11.3 million, $16.3 million, and $41.7 for the three months ended March 31, 2010, June 30, 2010, September 30, 2010, December 31, 2010, March 31, 2011, June 30, 2011, September 30, 2011, December 31, 2011, March 31, 2012, June 30, 2012, September 30, 2012, and December 31, 2012, respectively. Our quarterly results may fluctuate significantly as a result of a variety of factors, many of which are beyond our control. In particular, if our stock price increases or decreases in future periods during which our Series I warrants are outstanding, we will be required to recognize corresponding losses or gains related to the valuation of the Series I warrants that could materially impact our results of operations. If our quarterly results of operations fall below the expectations of securities analysts or investors, the price of our common stock could decline substantially. Fluctuations in our quarterly results of operations may be due to a number of factors, including, but not limited to, our ability to increase sales to existing customers and attract new customers, the addition or loss of large customers, construction cost overruns, down time at our facilities, the amount and timing of operating costs, unanticipated expenses, capital expenditures related to the maintenance and expansion of our business, operations and infrastructure, our debt service obligations, changes in the price of natural gas, changes in the prices of CNG and LNG relative to gasoline and diesel, changes in our pricing policies or those of our competitors, fluctuation in the value of our natural gas futures contracts, the costs related to the acquisition of assets or businesses, regulatory changes, increasing competition, and geopolitical events such as war, threat of war or terrorist actions. Investors in our stock should not rely on the results of one quarter as an indication of future performance as our quarterly revenues and results of operations may vary significantly in the future. Therefore, period-to-period comparisons of our operating results may not be meaningful.

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

        As of December 31, 2012, there were 87,634,478 shares of our common stock outstanding, 12,083,677 shares underlying outstanding options, 1,545,000 shares underlying restricted stock units, 2,130,682 shares underlying outstanding Series I warrants (all of which were sold in our registered direct offering that closed in November 2008), 5,000,000 shares underlying a warrant we issued in November 2012 to GE, and an aggregate of 16,262,226 shares underlying the convertible notes we issued in July 2011, August 2011 and July 2012. 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. Also, shares subject to outstanding options, warrants and convertible notes are eligible for sale in the public

34

market to the extent permitted by the provisions of various option, warrant and convertible note agreements and Rule 144, or if such shares have been registered for resale under the Securities Act (8,999,999 shares underlying convertible notes we issued in August 2011 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.

        Further, as of December 31, 2012, 18,139,720 shares of our common stock held by our co-founder and board member T. Boone Pickens are subject to pledge agreements with banks. Should one or more of the banks be forced to sell the shares subject to the pledge, the trading price of our stock could also decline. In addition, a number of our directors and executive officers have entered into Rule 10b5-1 Sales Plans with a broker to sell shares of our common stock that they hold or that may be acquired upon the exercise of stock options. Sales under these plans will occur automatically without further action by the director or officer once the price and/or date parameters of the particular selling plan are achieved. As of December 31, 2012, 348,500 shares in the aggregate were subject to future sales by our named executive officers and directors under these selling plans.

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

        As of December 31, 2012, T. Boone Pickens owned in the aggregate approximately 21.8% of our outstanding shares of common stock. As a result, Mr. Pickens will be able to influence or control matters requiring approval by our stockholders, including the election of directors and the approval of 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 stock. Conversely, this concentration may facilitate a change in control at a time when you and other investors may prefer not to sell.

Item 1B.    Unresolved Staff Comments.

        None.

Item 2.    Properties.

        Our corporate headquarters are located at 3020 Old Ranch Parkway, Suite 400, Seal Beach, California 90740, where we occupy approximately 43,067 square feet. Our office lease expires on March 31, 2018.

        We own and operate the Pickens Plant located in Willis, Texas, approximately 50 miles north of Houston. We own approximately 24 acres on which the plant is situated, along with approximately 34 acres surrounding the plant.

        We own an LNG liquefaction plant in Boron, California, approximately 125 miles from Los Angeles. In November 2006, we entered into a 30 year ground lease for the 36 acres on which this plant is situated, pursuant to which we pay annual base rent payments of $230,000 per year, plus up to $130,000 per year for each 30,000,000 gallons of production capacity utilized, subject to future adjustment based on consumer price index changes.

        We lease the space upon which we operate our RNG production facilities in Dallas, Texas and Canton, Michigan.

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        We lease a manufacturing facility in Chilliwack, British Columbia where we occupy approximately 81,000 square feet. The facility lease expires in January 2018.

Item 3.    Legal Proceedings.

        We are 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 and may continue to arise during the course of such audits as to facts and matters of law. It is impossible at this time to determine the ultimate liabilities that we may incur resulting from any lawsuits, claims and proceedings, audits, commitments, contingencies and related matters or the timing of these liabilities, if any. If these matters were to be ultimately resolved unfavorably, an outcome not currently anticipated, it is possible that such outcome could have a material adverse effect upon our consolidated financial position or results of operations. However, we believe that the ultimate resolution of such actions will not have a material adverse effect on our consolidated financial position, results of operations, or liquidity.

Item 4.    Mine Safety Disclosures.

        None.


PART II

Item 5.    Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.

Market Information

        Our common stock has been quoted on the Nasdaq Global Market under the symbol "CLNE" since May 25, 2007. Prior to that time, there was no public market for our stock. Set forth below are the high and low sales prices as reported by Nasdaq for our common stock for the periods indicated.

 
   Sales Prices  
 
   High   Low  

Fiscal Year 2011

              

First Quarter 2011

   $ 16.95   $ 11.75  

Second Quarter 2011

   $ 17.85   $ 12.13  

Third Quarter 2011

   $ 17.21   $ 10.75  

Fourth Quarter 2011

   $ 13.99   $ 9.02  

Fiscal Year 2012

              

First Quarter 2012

   $ 23.92   $ 12.95  

Second Quarter 2012

   $ 20.74   $ 12.55  

Third Quarter 2012

   $ 16.35   $ 13.06  

Fourth Quarter 2012

   $ 13.87   $ 11.00  

Holders

        There were approximately 72 stockholders of record as of February 22, 2013. We believe there are approximately 96,667 stockholders of our common stock held by brokerage firms on behalf of stockholders.

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Dividend Policy

        We have not paid any dividends to date and do not anticipate paying any dividends on our common stock in the foreseeable future. Further, the SLG Agreements (as defined and described in note 9 to our consolidated financial statements), restrict our ability to pay cash dividends on our common stock. We anticipate that all future earnings will be retained to finance future growth.

Performance Graph

        This performance graph shall not be deemed "filed" for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the Exchange Act), or incorporated by reference into any filing of Clean Energy Fuels Corp. under the Securities Act, or the Exchange Act, except as shall be expressly set forth by specific reference in such filing.

        The following graph shows a comparison for the five-year period ending December 31, 2012 of the cumulative total return for our common stock, the Nasdaq Global Market Index, and the Russell 2000 Growth Index. We chose to include the Russell 2000 Growth Index as a comparable index due to the lack of a comparable industry index or peer group. We are the only actively traded public company whose only line of business is to sell natural gas and the associated equipment and services necessary to use natural gas as a vehicle fuel. Such returns are based on historical results and are not intended to suggest future performance. Data for the Nasdaq Global Market Index and the Russell 2000 Growth Index assumes reinvestment of dividends.

GRAPHIC

*
Assumes $100 was invested on December 31, 2007 in our common stock, the Nasdaq Global Market Index, and the Russell 2000 Growth Index. The Nasdaq Global Market Index and the Russell 2000 Growth Index results include reinvestment of dividends.

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Item 6.    Selected Financial Data.

        You should read the following selected historical consolidated financial data in conjunction with "Management's Discussion and Analysis of Financial Condition and Results of Operations" and our consolidated financial statements and the related notes contained elsewhere in this annual report on Form 10-K.

        The consolidated statements of operations data for the years ended December 31, 2010, 2011, and 2012 and the consolidated balance sheet data at December 31, 2011, and 2012, are derived from our audited consolidated financial statements in this Form 10-K. The consolidated statements of operations data for the years ended December 31, 2008 and 2009, and the consolidated balance sheet data at December 31, 2008, 2009 and 2010 are derived from our audited consolidated financial statements that are not included in this Form 10-K. The historical results are not necessarily indicative of the results to be expected in any future period.

 
   Year Ended December 31,  
 
   2008   2009   2010   2011   2012  
 
   (In thousands, except share data)
  

Statement of Operations Data:

                                

Total Revenues(1)

   $ 125,867   $ 131,503   $ 211,834   $ 292,717   $ 334,008  

Operating expenses:

                                

Costs of sales

     98,768     82,921     141,889     216,684     253,684  

Derivative (gains) losses:

                                

Futures contracts

     611     —     —     —     —  

Series I warrant valuation

     —     17,367     (10,278 )   (2,655 )   (3,391 )

Selling, general and administrative(2)

     62,416     47,509     63,258     86,850     117,976  

Depreciation and amortization

     9,624     16,992     22,487     30,406     36,261  
                       

Total operating expenses:

     171,419     164,789     217,356     331,285     404,530  
                       

Operating loss

     (45,552 )   (33,286 )   (5,522 )   (38,568 )   (70,522 )

Interest income (expense), net

     1,630     (32 )   (1,194 )   (9,616 )   (16,069 )

Other income (expense), net

     (168 )   (310 )   2,080     (611 )   1,236  

Impairment of cost method investment

     —     —     —     —     (14,544 )

Income (loss) from equity method investments

     (188 )   244     427     637     331  
                       

Loss before income taxes

     (44,278 )   (33,384 )   (4,209 )   (48,158 )   (99,568 )

Income tax (expense) benefit

     (290 )   (304 )   1,436     703     (1,294 )
                       

Net loss

     (44,568 )   (33,688 )   (2,773 )   (47,455 )   (100,862 )

Loss (income) of noncontrolling interest

     105     439     257     (178 )   (393 )
                       

Net loss attributable to Clean Energy Fuels Corp

   $ (44,463 ) $ (33,249 ) $ (2,516 ) $ (47,633 ) $ (101,255 )
                       

Basic and diluted loss per share

   $ (0.98 ) $ (0.60 ) $ (0.04 ) $ (0.68 ) $ (1.16 )
                       

Weighted average common share outstanding:

                                

Basic and diluted

     45,367,991     55,021,961     62,549,311     70,415,431     87,455,073  
                       
(1)
Revenues include the following amounts:

 
   Year Ended December 31,  
 
   2008   2009   2010   2011   2012  

Fuel tax credits (VETC)

   $ 17,197   $ 15,535   $ 16,042   $ 17,889   $ —  
                       

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(2)
2008 amount includes $18.6 million of expenses to support Proposition 10 on the California ballot in November 2008 that was not adopted.

 
   December 31,  
 
   2008   2009   2010   2011   2012  

Balance Sheet Data:

                                

Cash and cash equivalents

   $ 36,284   $ 67,087   $ 55,194   $ 238,125   $ 108,522  

Restricted cash, short term

     2,500     2,500     2,500     4,792     8,445  

Short-term investments

     —     —     —     33,329     38,175  

Working capital

     47,338     78,799     65,070     312,372     170,778  

Total assets

     290,374     355,799     583,499     931,061     975,200  

Long-term debt, inclusive of current portion

     25,084     12,221     64,416     289,422     331,025  

Total Clean Energy Fuels Corp. Stockholders' equity

     233,777     277,189     413,287     540,884     542,713  

Item 7.    Management's Discussion and Analysis of Financial Condition and Results of Operations.

        The discussion in this section contains forward-looking statements. These statements relate to future events or our future financial performance. We have attempted to identify forward-looking statements by terminology such as "anticipate," "believe," "can," "continue," "could," "estimate," "expect," "intend," "may," "plan," "potential," "predict," "should," "would" or "will" or the negative of these terms or other comparable terminology, but their absence does not mean that a statement is not forward-looking. These statements are only predictions and involve known and unknown risks, uncertainties and other factors, which could cause our actual results to differ from those projected in any forward-looking statements we make. See "Risk Factors" in Part I, Item 1A of this annual report on Form 10-K for a discussion of some of these risks and uncertainties. This discussion should be read with our financial statements and related notes included elsewhere in this report.

        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 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 sell non-lubricated natural gas compressors and related equipment used in CNG stations and LNG stations, convert light and medium duty vehicles to run on natural gas, provide design and engineering services for natural gas engine systems, and produce renewable natural gas ("RNG"), which can be used as vehicle fuel or sold for power generation. In addition, we help our customers acquire and finance natural gas vehicles and obtain local, state and federal grants and incentives.

Overview

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

        Sources of revenue.    We generate revenues by selling CNG and LNG, providing operations and maintenance ("O&M") services to our vehicle fleet customers, designing and constructing fueling stations and selling or leasing those stations to our customers, selling RNG, selling converted natural gas vehicles, selling non-lubricated natural gas fueling compressors and related equipment and maintenance services, providing financing for our customers' natural gas vehicle purchases and selling tradable credits we generate by selling natural gas and RNG as a vehicle fuel, including credits ("LCFS Credits") under the California low carbon fuel standard.

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        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 to our customers at stations 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 in Peru, plus (iv) our proportionate share of the gasoline gallon equivalents of RNG produced and sold as pipeline quality natural gas by our RNG production facility in Dallas, Texas), (2) our gross margin (which we define as revenue minus cost of sales), and (3) net income (loss) attributable to us. The following table, which you should read in conjunction with our consolidated financial statements and notes contained elsewhere in this annual report on Form 10-K, presents our key operating data for the years ended December 31, 2010, 2011, and 2012:

Gasoline gallon equivalents delivered

 
   Year Ended December 31,  
 
   2010   2011   2012  
 
   (in millions)
  

CNG

     81.4     101.8     130.5  

RNG

     7.4     6.7     8.9  

LNG

     33.9     47.1     55.5  
               

Total

     122.7     155.6     194.9  
               

Operating data (in thousands)

                    

Gross margin

   $ 69,945   $ 76,033   $ 80,324  

Net loss attributable to Clean Energy Fuels. Corp

     (2,516 )   (47,633 )   (101,255 )

        Key trends in 2010, 2011 and 2012.    According to the EIA, demand for natural gas fuels in the United States increased by approximately 19% during the period January 1, 2010 through December 31, 2012. We believe this growth in demand was attributable primarily to the rising prices of gasoline and diesel relative to CNG and LNG during these periods and increasingly stringent environmental regulations affecting vehicle fleets.

        The number of fueling stations we served grew during the past three years from 196 at December 31, 2009 to 348 at December 31, 2012 (a 77.6% 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 2010 to 2012 increased by 58.8%. The increase in gasoline gallon equivalents delivered was the primary contributor to increased revenues during 2010, 2011 and 2012. In addition, beginning in 2011, we also benefitted from increased revenues from compressor sales and fueling station installations as a result of our acquisitions of IMW Industries, Ltd. ("IMW") and Wyoming Northstar Incorporated and its affiliated companies ("Northstar"), which occurred during the third and fourth quarters of 2010. In 2012, we sold four large transit stations for $40.3 million, which contributed to our revenue increase during the year.

        Our cost of sales also increased during these periods, which was attributable primarily to increased costs related to delivering more CNG and LNG to our customers in 2010 through 2012. In 2011, the cost of sales related to compressors sold through IMW and fueling station installations performed by Northstar also contributed to the increase. In 2012, the cost of sales related to increased station construction sales contributed to our increase in cost of sales.

        Since the last half of 2009, we have experienced reduced margins in certain markets, particularly in the municipal transit and refuse sectors. The reduction in margins is primarily a result of increased competition and sales agreements with larger entities that have greater pricing leverage. Also, in many cases, our agreements with our customers, including governmental agencies, are subject to a

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competitive bidding process and we have been required to reduce our prices to maintain our contracts as they come up for bid. In addition, in May and June of 2009, we acquired four compressed natural gas operations and maintenance services contracts with municipal transit agencies, and in 2010 and 2011, we won several contracts with a transit agency in California that have significant volume but smaller margins than we typically generate on our fuel sales. As a result of all of these factors, the overall average margin on our fuel sales across our business decreased in 2011.

        We believe that our margins on fuel sales will improve in the future to the extent we are successful in increasing our retail CNG and LNG fueling operations, which is where we earn our highest margins. If our retail CNG and LNG fueling operations do not grow, we may experience further reduced margins. We may also lose contracts with governmental customers if we are unwilling or unable to reduce our prices or lose in the competitive bidding process, which would reduce our volumes. We will need to increase our business with non-government entities to replace volumes lost in competitive bid procurements when we are not successful in retaining the contracts.

        During 2011 and 2012, prices for oil, gasoline, and diesel fuel were generally substantially higher than the price for natural gas. Oil hit a high of $107.07 in February 2012 and settled at $91.82 per barrel on December 31, 2012. In California, average retail prices for gasoline were $3.68 per gallon in January 2012 and hit a high of $4.71 per gallon in October 2012 before moving down to $3.60 per gallon at December 31, 2012. Average retail prices for diesel fuel in California were $4.05 per diesel gallon in January 2012 and hit a high of $4.50 per diesel gallon in September 2012 before moving down to $4.05 per diesel gallon at December 31, 2012. Higher gasoline and diesel prices improve our margins on fuel sales to the extent we price our fuel at a discount to gasoline or diesel and natural gas prices do not increase by a corresponding amount. During this time period, the price for natural gas increased slightly. The NYMEX price for natural gas ranged from $3.08 per MMbtu in January 2012 to $3.71 per MMbtu in December 2012. The average retail sales price of our CNG fuel sold in the Los Angeles metropolitan area ranged from $2.75 per gallon for the month of January 2012 to $2.84 per gallon for the month of December 2012. The average retail sales price of our LNG fuel sold in the Los Angeles metropolitan area ranged from $2.48 per gallon during January 2012 to $2.70 per gallon for the month of December 2012.

        Recent developments.    In April 2012, we exercised our option to acquire the remaining 80.1% of ServoTech Engineering, Inc. ("ServoTech"), a company that provides design and engineering services for natural gas fueling systems among other services, for $2.8 million.

        In July 2012, we received $50.0 million from Chesapeake NG Ventures Corporation ("Chesapeake") in accordance with our note arrangement (see note 9 to our consolidated financial statements).

        In November 2012, we entered into a finance arrangement with General Electric ("GE") to finance the acquisition of two LNG plants (see notes 9 and 11 to our consolidated financial statements).

        In January 2013, certain federal fuel tax credits were extended through December 31, 2013 and made retroactive to January 1, 2012. The amount attributed to 2012, estimated to be $20.8 million, will be recorded by us in the first quarter of 2013, the period in which the law was passed.

        We have agreed to sell our ownership interest in our joint venture in Peru for approximately $6.1 million after receiving a dividend distribution of approximately $1.0 million (see notes 7 and 19 to our consolidated financial statements). We expect to close the sale by March 31, 2013.

        In January and February 2013, an aggregate of $4.0 million of principal and accrued interest under an SLG Note was converted by the holder into 268,664 shares of our common stock (see notes 9 and 19 to our consolidated financial statements).

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        Anticipated future trends.    We anticipate that, over the long term, the prices for gasoline and diesel will continue to be significantly higher than the price of natural gas as a vehicle fuel, and more stringent emissions requirements will continue to make natural gas vehicles an attractive alternative to traditional gasoline and diesel powered vehicles. 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 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 and enhance our leadership position as this market expands. With our acquisitions of IMW and Northstar, we are a fully integrated provider of advanced compression technology, station-building and fueling. We also anticipate expanding our sales of CNG and LNG in the other markets in which we operate, including trucking, refuse hauling, airports, taxis and public transit. 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 or LNG production capacity, as well as the logistics of delivering more CNG and LNG 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 additional capital. Additionally, we have and will continue to increase our sales and marketing team and other necessary personnel as we seek to expand our existing markets and enter new markets, which will also result in increased costs.

        We anticipate the commercial roll-out of natural gas engines that are well-suited for the U.S. heavy-duty over-the-road ("OTR") trucking market, together with the economic and environmental benefits of natural gas fuel, will result in increased adoption of natural gas fueled trucks by the U.S. trucking industry. Heavy-duty trucks in the United States are generally high-volume consumers of vehicle fuel, and we believe many use 20,000 gallons or more per truck per year, and the lower cost of natural gas compared to regular gasoline and diesel would result in substantial fuel savings for the operator. With over eight million heavy-duty trucks registered in the U.S. market, we believe that this market may become our largest market. As a result, we have made a significant commitment of capital and other resources to build a nationwide network of LNG truck fueling stations, which we refer to as "America's Natural Gas Highway," or "ANGH," on the interstate highway system and in major metropolitan areas that will enable natural gas fueled freight trucking coast to coast and border to border within the 48 continental states. We expect America's Natural Gas Highway to initially include approximately 150 truck fueling stations, of which 70 ANGH stations were completed at the end of 2012. Of these 70 stations, seven are open and selling LNG, and the remainder are planned to open as natural gas engines that are well-suited for the trucking market (including the CWI 11.9 liter engine) become available and trucks powered by such engines are deployed in the geographic areas where the stations are located. We expect to build approximately 50 - 70 additional ANGH stations in 2013, depending upon the deployment of natural gas trucks, demand for LNG, and our ability to identify and obtain suitable locations for LNG stations, among other things. Many ANGH stations are located at Pilot-Flying J Travel Centers already serving goods movement trucking.

        Many governmental entities, which represented approximately 28% of our revenues from 2010 through 2012, are experiencing significant budget deficits and have been, and may continue to be, unable to invest in new natural gas vehicles for their transit or refuse fleets. They may also be compelled to reduce public transportation and services, or the prices they pay for these services, which would negatively affect our business.

        Sources of liquidity and anticipated capital expenditures.    Liquidity is the ability to meet present and future financial obligations either through operating cash flows, the sale or maturity of existing assets, or by the acquisition of additional funds through capital management. Historically, our principal sources of liquidity have consisted of cash provided by operations and financing activities.

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        Our business plan calls for approximately $186.2 million in capital expenditures in 2013, primarily related to construction of new fueling stations, including ANGH stations, expanding and constructing our LNG plants, expanding and building landfill gas processing plants, and the purchase of LNG trailers. We may also elect to invest additional amounts in companies or assets in the natural gas fueling infrastructure, services and production industries, including RNG production, and to make capital expenditures to build additional LNG production facilities or to otherwise secure future LNG supply. We will need to raise additional capital as necessary to fund any capital expenditures or investments that we cannot fund through available cash or cash generated by operations. The timing and necessity of any future capital raise will depend on our rate of new station construction and potential merger or acquisition activity. For more information, see "Liquidity and Capital Resources" and "Capital Expenditures" below. We may not be able to raise capital on terms that are favorable to existing stockholders or at all. Any inability to raise capital may impair our ability to invest in new stations, develop natural gas fueling infrastructure and invest in strategic transactions or acquisitions and may reduce our ability to grow our business and generate 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 I, Item 1A of this report.

Operations

        We generate revenues by selling CNG and LNG and providing O&M services to our vehicle fleet customers. For the year ended December 31, 2012, CNG and RNG (together) represented 72% and LNG represented 28% 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 RNG, sales of natural gas vehicles, sales of advanced natural gas fueling compressors and related equipment and maintenance services, providing financing for our customers' natural gas vehicle purchases, and selling RINs and LCFS Credits.

CNG Sales

        We sell CNG through fueling 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 brokers under standard, floating-rate arrangements and then compress and dispense it into our customers' vehicles. Our CNG sales are made primarily through contracts with our fleet 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. We also sell a small amount of CNG under fixed-price contracts. We will continue to offer fixed price contracts as appropriate and consistent with our natural gas hedging policy. Our fleet customers typically are billed monthly based on the volume of CNG sold at a station. The remainder of our CNG sales are on a per fill-up basis at prices we set at the pump based on prevailing market conditions. These customers typically pay using a credit card at the station.

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, and we plan to build two new LNG plants in connection with our strategic collaboration with GE. We expect that these additional plants, as well as our planned expansion of our Boron, California plant, and other plants to be built by us or third parties in the future, will be necessary to secure sufficient sources of LNG for ANGH.

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        We sell LNG to fleet customers, who typically own and operate their fueling stations. Increasingly, we also sell LNG to fleet and other customers at our public-access LNG stations. During 2012, we procured 44% of our LNG from third-party producers, and we produced the remainder of the LNG at our liquefaction plants in Texas and California. We expect to enter additional purchase contracts with third party LNG producers in the future. For LNG that we purchase from third parties, we have entered into, and may enter into additional "take or pay" contracts that require us to purchase minimum volumes of LNG at index-based rates. We deliver LNG via our fleet of 64 tanker trailers to fueling stations, where it is stored and dispensed in liquid form into vehicles. We sell LNG principally through supply contracts that are priced on either a fixed-price or 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 will continue to offer fixed price contracts as appropriate and consistent with our natural gas hedging policy. Our LNG contracts provide that we charge our customers periodically based on the volume of LNG supplied. We also sell LNG on a per fill-up basis at prices we set at the pump based on prevailing market conditions. These customers typically pay using a credit card at the station.

Government Incentives

        From October 1, 2006 through December 31, 2011, we received a federal fuel tax credit ("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 were able to claim 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.

        The American Taxpayer Relief Act, signed into law on January 2, 2013, provides one-year extensions for several tax credits affecting alternative fuels, including the $0.50 per gallon alternative-fuel tax credit for CNG and LNG. The tax credits were extended through December 31, 2013 and made retroactive to January 1, 2012. Such credits for 2012 are estimated to be $20.8 million, which will be recognized during the first quarter of 2013, the period in which the extension was signed into law.

        On July 15, 2010, the IRS sent us a letter (i) disallowing approximately $5.1 million related to certain claims we made from October 1, 2006 to June 30, 2008 under the VETC program, and (ii) seeking repayment of such amount. After negotiations with the IRS and the other impacted parties, we settled the dispute for $2.1 million in 2012.

Operation and Maintenance

        We generate a portion of our revenue from operation and maintenance agreements for CNG and LNG fueling stations where we do not supply the fuel. We refer to this portion of our business as "O&M." At these fueling stations the customer contracts directly with a local broker or utility to purchase natural gas. For O&M services, we do not sell the fuel itself, but 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.

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Station Construction

        We generate a portion of our revenue from designing and constructing fueling stations and selling or leasing the stations to our customers. For these projects, we act as general contractor or supervise qualified third-party contractors. We charge construction fees or lease rates based on the size and complexity of the project.

Vehicle Acquisition and Finance

        We offer vehicle finance services for some of our customers' purchases of natural gas vehicles or the conversion of their existing gasoline or diesel powered vehicles to operate on natural gas. We loan to certain qualifying customers a portion of, and on occasion up to 100% of, the purchase price of their natural gas vehicles. We may also lease vehicles in the future. 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 December 31, 2012, we have not generated significant revenue from vehicle financing activities.

RNG

        We own a 70% interest in a RNG production facility at the McCommas Bluff landfill located in Dallas, Texas. We sell RNG produced at the facility to Shell Energy North America under a Gas Sale Agreement and, depending upon RNG production volumes, we have the ability to sell RNG as a vehicle fuel. We own a second 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 (the effectiveness of such contract is subject to the CEC certifying the facility). We are building a third RNG facility at a Republic Services landfill in North Shelby, Tennessee, and we expect the facility to be operational during the first quarter of 2014. We are seeking to expand our RNG business by pursuing additional RNG production projects. We sell some of the RNG we currently produce, and expect to sell a significant amount of the RNG we produce at the facilities we are building and plan to build, through our natural gas fueling infrastructure for use as a vehicle fuel. In addition, we plan to purchase RNG from third party producers, and sell that RNG for vehicle use through our fueling infrastructure.

Vehicle Conversions

        Our subsidiary, BAF Technologies, Inc. ("BAF"), provides natural gas vehicle ("NGV") conversions, alternative fuel systems, application engineering, service and warranty support and research and development. BAF's vehicle conversions include taxis, vans, pick-up trucks and shuttle buses. BAF utilizes advanced natural gas system integration technology and has certified NGVs under both EPA and CARB standards achieving Super Ultra Low Emission Vehicle emissions. In 2012, we completed our purchase of all of ServoTech. ServoTech provides, among other services, design and engineering services for natural gas engine systems. We generate revenues through the sale of natural gas vehicles that have been converted to run on natural gas by BAF, and design and engineering services for natural gas engine systems by ServoTech. The majority of BAF's revenue during 2010 and 2011 was derived from sales of converted natural gas service vans to AT&T. For the years ended December 31, 2011 and 2012, BAF and ServoTech combined contributed approximately $23.6 million, and $24.3 million, respectively, to our revenue.

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Natural Gas Fueling Compressors

        Our subsidiary, IMW, manufactures and services non-lubricated natural gas fueling compressors and related equipment for the global natural gas fueling market. IMW is headquartered near Vancouver, British Columbia, has other manufacturing facilities near Shanghai, China, and in Ferndale, Washington, and has sales and service offices in Bangladesh, Colombia, Peru and the United States. For the years ended December 31, 2011 and 2012, IMW contributed approximately $69.1 million and $64.5 million, respectively, to our revenue.

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 RINs when we sell RNG for use as a vehicle fuel. We can sell these RINs and LCFS Credits to third parties who need the RINs and the LCFS Credits to comply with federal and state requirements. In 2012, we realized $2.9 million in revenue through the sale of LCFS Credits. We anticipate that we will generate and sell increasing numbers of RINs and LCFS Credits as we grow our business and sell escalating amounts of CNG, LNG and RNG for use as a vehicle fuel.

Volatility of Earnings and Cash Flows

        During 2010, 2011, and 2012, our futures contracts qualified for hedge accounting, so we had no derivative gains or losses recognized in our consolidated statements of operations for these periods. In accordance with our natural gas hedging policy, we plan to structure all futures contracts as cash flow hedges under the applicable derivative accounting guidance, but we cannot be certain that they will qualify. See "Risk Management Activities" below. If the futures contracts do not qualify for hedge accounting, we could incur significant increases or decreases in our earnings based on fluctuations in the market value of the contracts from period to period.

        Additionally, we are required to maintain a margin account to cover losses related to our natural gas futures contracts. Futures contracts are valued daily, and if our contracts are in loss positions at the end of a trading day, our broker will transfer the amount of the losses from our margin account to a clearinghouse. If at any time the funds in our margin account drop below a specified maintenance level, our broker will issue a margin call that requires us to restore the balance. Consequently, these payments could significantly impact our cash balances. At December 31, 2012, we had paid $0.6 million in margin deposits, which are included in prepaid expenses and other current assets in our consolidated balance sheet.

        The decrease in the value of our futures positions and any corresponding margin deposits required thereon could significantly impact our financial position in the future.

Volatility of Earnings Related to Series I Warrants

        Beginning January 1, 2009, 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 $2.7 million and $3.4 million related to recording the estimated fair market value changes of our Series I warrants in the years ended December 31, 2011 and December 31, 2012, respectively. See note 18 to our consolidated financial statements contained elsewhere herein. 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. On November 10, 2010, 1,183,712 of the Series I warrants were exercised. As of December 31, 2012, 2,130,682 of the Series I warrants remained outstanding.

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Volatility of Earnings Related to Contingent Consideration

        Under business combination accounting guidance, we are required to record the change in the value of the contingent consideration related to our acquisitions of both BAF and IMW in our financial statements through the contingency period, which expired December 31, 2011 for BAF and expires on March 31, 2014 for IMW.

        If the anticipated results of IMW increase or decrease during future periods, we may be required to recognize material losses or gains based on the valuation of the increased or decreased consideration due to the former IMW shareholder. During 2012, we recognized a gain of $4.1 million related to the estimated change in value of the IMW contingent consideration. Our earnings or loss per share may be materially affected by future gains or losses we are required to recognize as a result of changes in the estimated fair value of the contingent consideration amount.

Debt Compliance

        In connection with our acquisition of IMW, we entered into a credit agreement with HSBC that requires IMW to comply with certain financial covenants (see note 9 to our consolidated financial statements). If we were to violate a covenant, we would seek a waiver from the bank, which the bank is not obligated to grant. If the bank does not grant a waiver, all of the obligations under the credit agreement would be due and payable. IMW was in compliance with these covenants as of December 31, 2012.

        The Indenture and the Loan Agreement entered into by Dallas Clean Energy McCommas Bluff, LLC ("DCEMB"), our 70% owned subsidiary, as part of issuing its Revenue Bonds, as defined and disclosed in note 9 to our consolidated financial statements, have certain non-financial debt covenants with which DCEMB must comply. As of December 31, 2012, DCEMB was in compliance with its debt covenants.

        The loan agreement we entered into as part of issuing the CHK Notes, as defined and discussed elsewhere in this Item 7 and in note 9 to our consolidated financial statements, has certain non-financial debt covenants with which we must comply. As of December 31, 2012, we were in compliance with these debt covenants.

        The Convertible Note Purchase Agreements we entered into as part of issuing the SLG Notes, as defined and discussed in note 9 to our consolidated financial statements, have certain non-financial debt covenants with which we must comply. As of December 31, 2012, we were in compliance with these covenants.

        The GE Credit Agreement, as defined and discussed in note 9 to our consolidated financial statements, contains certain covenants with which we must comply. As of December 31, 2012, we were in compliance with these covenants.

Risk Management Activities

        Some of our natural gas fuel sales contracts require us to sell LNG or CNG to our customers at a fixed price. These contracts expose us to the risk that the price of natural gas may increase above the natural gas cost component included in the price at which we are committed to sell gas to our customers.

        In an effort to mitigate the volatility of our earnings related to our futures contracts and to reduce our risk related to fixed price sales contracts, we operate under a natural gas hedging policy pursuant to which we only purchase futures contracts to hedge our exposure to variability in expected future cash flows related to a particular fixed price contract or bid. Subject to the conditions set forth in the policy, we purchase futures contracts in quantities reasonably expected to effectively hedge our

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exposure to cash flow variability related to such fixed price sales contracts entered into after the date of the policy. Unless otherwise agreed in advance by the board of directors and the derivative committee, we will conduct our futures activities and enter into fixed price sales contracts only in accordance with the natural gas hedging policy, a complete copy of which, as amended effective May 29, 2008, was filed as Exhibit 99.1 to our Form 8-K filed with the SEC on June 20, 2008. The summary of the policy described above does not purport to be complete and is qualified in its entirety by reference to the copy of the policy previously filed.

        Due to the restrictions of our revised hedging policy, we expect to offer fewer fixed price sales contracts to our customers. If we do offer a fixed price sales contract, we anticipate including a price component that would cover our estimated cash requirements over the duration of the underlying futures contracts. The amount of this price component will vary based on the anticipated volume and the natural gas price component to be covered under the fixed price sales contracts.

Critical Accounting Policies

        Our discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements, which have been prepared in accordance with U.S. generally accepted accounting principles ("US GAAP"). The preparation of financial statements requires management to make estimates and judgments that affect the reported amounts of assets and liabilities, revenue and expenses, and disclosures of contingent assets and liabilities as of the date of the financial statements.

        On a periodic basis, we evaluate our estimates, including those related to revenue recognition, asset realization, accounts receivable reserves, notes receivable reserves, warranty reserves, derivative values, income taxes, and the fair value of equity instruments granted as stock-based compensation. We use historical experience, market quotes, and other assumptions as the basis for making estimates. Actual results could differ from those estimates under different assumptions or conditions. We believe the following critical accounting policies affect our more significant judgments and estimates used in the preparation of our consolidated financial statements.

Impairment of Goodwill and Long-lived Assets

        Before 2011, we evaluated the carrying value of goodwill during the fourth quarter of each fiscal year and between annual evaluations if events occurred or circumstances changed that would more likely than not reduce the fair value of the goodwill below its carrying amount. Beginning in 2011, we performed our evaluation of the carrying value of Goodwill under the amended guidance issued by the FASB in Accounting Standards Update ("ASU") 2011-08, Testing for Goodwill Impairment, issued in September 2011, which we chose to early adopt. Under the amended requirements of ASU 2011-08, an entity is not required to quantitatively determine a reporting unit's fair value if it concludes, based upon a qualitative assessment, that it is not more likely than not that the reporting unit's fair value is less than its carrying amount. The guidance also allows us to proceed directly to a quantitative analysis on an individual reporting unit basis, which we do when there is doubt about whether or not a qualitative assessment is sufficient or when there is an indicator of impairment. Beginning on October 1, 2012, we performed our test for indefinite-lived intangible assets impairment under the amended guidance issued by the FASB in ASU 2012-02, Testing Indefinite-Lived Intangible Assets for Impairment, issued in July 2012, which we chose to early adopt, effective October 1, 2012. The amended requirements of ASU 2012-02 provide a similar framework for testing indefinite-lived intangible assets for impairment as ASU 2011-08 does for testing goodwill for impairment. There were no impairment charges for goodwill or indefinite-lived intangible asset resulting from the October 1, 2011 or 2012 impairment testing, and no events have occurred subsequent to October 1, 2012 which indicate impairment may have occurred as of December 31, 2012.

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        We test tangible and intangible long-lived assets with definite useful lives for impairment whenever circumstances or events may affect the recoverability of the long-lived assets. The evaluation is primarily dependent on the estimated future cash flows of the assets and the fair value of these items, as determined by management based on a number of estimates, including future cash flow projections, discount rates and terminal values. In determining these estimates, management considers internally generated information and information obtained from discussions with market participants. The determination of fair value requires significant judgment both by management and outside experts engaged to assist in this process.

        The impairment test for long-lived assets is a two step process. The first step is to assess if events or changes in circumstances have affected the recoverability of long-lived assets. If management believes that recoverability has been affected, then step two requires management to calculate the undiscounted future cash flow related to the asset or asset group and to compare the cash flow to the carrying value of the asset or asset group. If the undiscounted future cash flows exceed the carrying value, then there is no impairment.

        During the fourth quarter of 2010, we recorded an impairment charge of $1.5 million related to an operating and maintenance contract we lost in a competitive bid to a competitor. In addition, during the fourth quarter of 2010, our subsidiary, Dallas Clean Energy, LLC ("DCE"), our wholly owned subsidiary and 70% owner of DCEMB, expensed approximately $0.7 million of costs related to equipment that was replaced as part of its expansion of the McCommas Bluff landfill in Dallas, Texas. In 2012, we recorded an impairment charge of $14.5 million related to our investment in VPG. We had no impairment charges during 2011.

Warranty Reserves

        Our warranty periods range up to thirty-six months, depending on the product or service. We provide a warranty reserve for estimated product warranty costs at the time the applicable sale is recognized. We continuously monitor and analyze warranty claims and maintain a reserve for the related warranty costs based on historical experience and future assumptions. If actual failure rates and the resulting cost of repair vary from our estimates, revisions to the estimated warranty reserve would be required.

Natural Gas Derivative Activities

        FASB authoritative guidance for our derivative instruments, specifically for our natural gas futures contracts, requires the recognition of all derivatives as either assets or liabilities in the consolidated balance sheet and the measurement of those instruments at fair value. For those contracts that do not qualify for hedge accounting, we record the changes in the fair value of the derivatives directly to our consolidated statements of operations. For those contracts that do qualify for hedge accounting, we record the changes in the fair value in our consolidated balance sheet as a component of stockholders' equity. We determine the fair value of our derivatives at the end of each reporting period based on quoted market prices from the NYMEX discounted to reflect the time value of money for contracts related to future periods.

        The counter-party to our derivative transactions is a high credit quality counterparty, however, we are subject to counterparty credit risk to the extent the counterparty is unable to meet its settlement commitments. We manage this credit risk by minimizing the number and size of our derivative contracts and by actively monitoring the creditworthiness of our counterparties. We record valuation adjustments against the derivative assets to reflect counterparty risk, if necessary. The counterparty is also exposed to credit risk by us, which requires us to provide cash deposits as collateral when our contracts are in a liability position in the aggregate.

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Revenue Recognition

        We recognize revenue on our CNG and LNG gas sales and for our O&M services in accordance with US GAAP, which requires that four basic criteria must be met before revenue can be recognized: (1) persuasive evidence of an arrangement exists; (2) delivery has occurred and title and the risks and rewards of ownership have been transferred to the customer or services have been rendered; (3) the price is fixed or determinable; and (4) collectability is reasonably assured. Applying these factors, we typically recognize revenue from the sale of natural gas at the time fuel is dispensed or, in the case of LNG sales agreements, delivered to our customers' storage facilities. We recognize revenue from O&M agreements as we provide the related services.

        In certain transactions with our customers, we agree to provide multiple products or services, including construction of and sale of a station, providing O&M to the station, and sale of fuel to the customer. We evaluate the separability of revenues based on current FASB authoritative guidance, which provides a framework for establishing whether or not a particular arrangement with a customer has one or more revenue elements. Prior to 2010, to the extent we had adequate objective evidence of the values of the separate elements indentified as part of a contract, we allocated the revenue from the contract on a relative fair value basis at the inception of the arrangement. During 2008 and 2009, we did not have objective evidence for our multi-element arrangements, which generally resulted in the deferral of revenue until the future services are performed. Since 2010, however, we have applied newly issued FASB authoritative guidance that allows us to use a combination of objective and reliable evidence to develop management's best estimate of the fair value of the undelivered element. If the arrangement contains a lease, we use the existing evidence of fair value to separate the lease from the other elements in the arrangement. The arrangement's consideration that is fixed or determinable is then allocated to each separate unit of accounting based on the estimated relative selling price of each deliverable, which is determined based on the historical data derived from our stand alone projects. The revenue allocated to the construction of station is recognized using completed-contract method. The revenue allocated to the O&M and sale of fuel is recognized ratably over the term of the arrangement.

        We recognize revenue related to our leasing activities in accordance with current FASB authoritative guidance. Our existing station leases are sales-type leases, giving rise to profit at the delivery of the leased station. Unearned revenue is amortized into income over the life of the lease using the effective-interest method. For those arrangements, we recognize gas sales and O&M service revenues as earned from the customer on a volume-delivered basis.

        We typically recognize revenue on fueling station construction projects where we sell the station to the customer using the completed-contract method. The construction contract is considered to be substantially completed at the earlier of customer acceptance of the fueling station or the time when the fuel dispensing activities begin. When applicable, multi-station construction contracts are segmented into phases as negotiated with customers. Gross margin related to each phase is recognized at its substantial completion. For IMW and Northstar, we use the percentage-of-completion method of accounting. In those circumstances, revenue is recognized as work on a contract progresses, based on cost incurred in relation to total estimated costs to be incurred for that project.

        We recognize revenue on RNG sales and vehicle sales when we transfer title of the gas or vehicle to our customer.

Stock-Based Compensation

        We recognize compensation expense related to stock options granted to employees based on the grant date fair value. Our assessment of the estimated fair value of the stock options granted is affected by our stock price as well as assumptions regarding a number of complex and subjective variables and the related tax impact. We use the Black-Scholes model to estimate the fair value of stock options granted.

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        The Black-Scholes option valuation model was developed for use in estimating the fair value of traded options that have no vesting restrictions and are fully transferable. This model also requires the input of certain assumptions, including: the expected volatility of our common stock price, expected dividends, if any, expected life of the stock option, and the risk free interest rate appropriate for the expected holding period.

Income Taxes

        We compute income taxes under the asset and liability method. This method requires the recognition of deferred tax assets and liabilities for temporary differences between the financial reporting basis and the tax basis of our assets and liabilities. The impact on deferred taxes of changes in tax rates and laws, if any, are applied to the years during which temporary differences are expected to be settled and are reflected in the consolidated financial statements in the period of enactment. We record a valuation allowance against any deferred tax assets when management determines it is more likely than not that the assets will not be realized. When evaluating the need for a valuation analysis, we use estimates involving a high degree of judgment including projected future income and the amounts and estimated timing of the reversal of any deferred tax liabilities.

        We operate within multiple domestic and foreign taxing jurisdictions and are subject to audit in these jurisdictions. These audits can involve complex issues, which may require an extended period of time for resolution. Although we believe that adequate consideration has been given to such issues, it is possible that the ultimate resolution of such issues could be significantly different than originally estimated.

Fair Value Estimates

        We have established a framework for measuring fair value in accordance with authoritative guidance. The framework includes 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.

        Our significant uses of fair value measurements include:

    •
    Recorded values of available-for-sale securities,

    •
    Allocation of the purchase price paid to acquire businesses to the assets acquired and liabilities assumed in those acquisitions,

    •
    Assessments of impairment of long-lived assets,

    •
    Assessments of impairment of goodwill,

    •
    Recorded values of derivative instruments,

    •
    Recorded values of contingent consideration obligations, and

    •
    Recorded values of warrants to purchase our common stock.

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Recently Issued Accounting Pronouncements

        See Note 1 to our consolidated financial statements contained elsewhere herein.

Results of Operations

Fiscal Year Ended December 31, 2012 Compared to Fiscal Year Ended December 31, 2011

        Revenue.    Revenue increased by $41.3 million to $334.0 million in the year ended December 31, 2012, from $292.7 million in the year ended December 31, 2011. A portion of this increase was the result of an increase in the number of gallons delivered between periods from 155.6 million gasoline gallon equivalents to 194.9 million gasoline gallon equivalents. The increase in volume was primarily from an increase in CNG sales of 28.7 million gallons. Our net increase in CNG volume was primarily from 18 new refuse customers, 12 new airport customers, five new transit customers, one new station added for an existing transit customer, five new trucking customers, and one new public customer, which together accounted for 19.5 million gallons of the CNG volume increase. We also experienced an increase of 9.2 million gallons in CNG volume between periods from our existing airport, transit, refuse and trucking customers, combined with the volume growth from our share of our joint venture in Peru. Further, we experienced an increase of 8.4 million in LNG volume between periods, which was primarily due to a combination of 3.6 million gallons from Northstar O&M services and 4.8 million gallons from 12 new trucking, transit, industrial and refuse customers. We experienced an increase in our RNG sales (through our 70% share of the RNG sales at DCEMB) of 2.2 million gallons due to increased RNG production at DCEMB's facility. We experienced a $42.7 million increase, excluding Northstar and IMW, in station construction revenues between periods, primarily due to the completion of seven new CNG stations for new refuse customers, two CNG station upgrades for two existing refuse customers, one new CNG station for an existing refuse customer, five new CNG stations for new trucking customers, one new CNG station for an existing trucking customer, four new CNG stations for an existing transit customer, two new CNG stations for new transit customers, two CNG station upgrades for an existing transit customer, and one new CNG station for a new airport customer. Also contributing to the revenue increase between periods were $2.9 million of LCFS credits that we recognized in 2012 due to the lifting, during the year ended December 31, 2012, of a federal court injunction that had prohibited enforcement of the California Low Carbon Fuel Standard. Revenue also increased by $0.6 million between periods due to increased sales of natural gas vehicle equipment by BAF. These increases were offset by the decrease in our effective price per gallon that we charged to our customers between periods. Our effective price per gallon charged was $0.81 for the year ended December 31, 2012, which represents a $0.05 per gallon decrease from $0.86 in the year ended December 31, 2011. The decrease was due to a combination of lower natural gas prices in 2012, upon which we base a portion of our pricing to our customers, and a higher percentage of O&M contracts between periods, which generate less revenue per gallon than contracts where we supply the natural gas commodity. Revenue attributable to VETC also decreased between periods because the credits were not available in 2012. However, subsequent to the 2012 year end, the credits were reinstated for 2013 and made retroactive to January 1, 2012. We recorded $17.9 million of revenue related to fuel tax credits in 2011, and we will record our 2012 VETC credits in the first quarter of 2013. We also recorded a $2.1 million reduction in revenue in 2012 related to the settlement of our dispute with the IRS over certain VETC claims. Revenue attributable to IMW and Northstar decreased between periods by $4.6 million and $4.3 million, respectively.

        Cost of sales.    Cost of sales increased by $37.0 million to $253.7 million in the year ended December 31, 2012, from $216.7 million in the year ended December 31, 2011. Our cost of sales primarily increased between periods as a result of delivering more volume to our customers. We also experienced a $41.4 million increase, excluding Northstar and IMW, in station construction costs between periods. We also experienced a $1.9 million increase in costs related to BAF's vehicle equipment sales between periods as BAF experienced certain production issues during the period.

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These increases were offset by a decrease in our effective cost per gallon of $0.11 per gallon, to $0.51 per gallon for 2012. This decrease was the result of lower natural gas costs and a higher percentage of O&M contracts in 2012, which generate a lower effective cost per gallon than contracts where we pay for the natural gas consumed at the stations. Costs that IMW and Northstar incurred decreased between periods by $7.4 million and $2.0 million, respectively.

        Derivative (gain) loss on Series I warrant valuation.    Derivative gains increased by $0.7 million to $3.4 million in the year ended December 31, 2012, from $2.7 million in the year ended December 31, 2011. These 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 18 to our consolidated financial statements contained elsewhere herein).

        Selling, general and administrative.    Selling, general and administrative expenses increased by $31.1 million to $118.0 million in the year ended December 31, 2012, from $86.9 million in the year ended December 31, 2011. The increase is primarily related to our continued business growth. Salaries and employee benefits increased by $11.1 million between periods, primarily due to a higher average employee headcount throughout 2012 as compared to 2011. During 2011, headcount increased from 710 at January 1, 2011 to 1,036 at December 31, 2011 as we increased our workforce to build the initial phase of America's Natural Gas Highway and to prepare for our anticipated business growth. During 2012, our headcount remained fairly constant with 1,038 employees at December 31, 2012. We experienced a $9.5 million increase in consulting, employee recruiting, business insurance, rent and occupancy, research and development, software/hardware maintenance and office supplies expenses between periods. Our travel and entertainment expenses increased by $2.2 million between periods, primarily due to the increased travel of our sales team to support our continued business growth and to develop new customers in the heavy-duty trucking market. Our bad debt expense increased $1.0 million between periods principally related to our vehicle financing activities. Also contributing to the increase between periods was an increase in stock based compensation expense of $8.6 million. These increases were offset by $1.3 million in additional gains in 2012 related to a decrease in the estimated fair value of the IMW contingent consideration liability between periods.

        Depreciation and amortization.    Depreciation and amortization increased by $5.9 million to $36.3 million in the year ended December 31, 2012, from $30.4 million in the year ended December 31, 2011. This increase was primarily due to additional depreciation expense in 2012 related to increased property and equipment balances between periods, primarily related to our expanded station network, including our build-out efforts of America's Natural Gas Highway. In addition, our amortization expense in 2012 includes increased amortization expense related to our ServoTech acquisition that we completed on April 30, 2012.

        Interest expense, net.    Interest expense, net, increased by $6.5 million to $16.1 million for the year ended December 31, 2012, from $9.6 million for the year ended December 31, 2011. This increase was primarily the result of an increase in interest expense due to the $200 million of convertible notes we issued in July and August of 2011 that had a full year of interest expense in 2012, and the additional $50 million convertible note we issued to Chesapeake in July 2012. (see note 9 to the consolidated financial statements for a full description of our outstanding debt).

        Other income (expense), net.    Other income (expense), net, increased by $1.8 million to $1.2 million of income for the year ended December 31, 2012, compared to expense of $0.6 million for the year ended December 31, 2011. This increase was primarily due to foreign currency exchange rate changes between periods on our IMW purchase notes (see note 9 to the consolidated financial statements).

        Impairment of cost method investment.    During the fourth quarter of 2012, we determined there was a decrease in value of our cost method investment in The Vehicle Production Group, LLC that was

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other than temporary and accordingly recognized an impairment charge for the full value of our investment of $14.5 million.

        Income (loss) from equity method investment.    During 2012, we recorded $0.3 million of equity in the income of our 49% interest in our Peruvian joint venture, compared to $0.6 million in 2011.

        Loss (income) of noncontrolling interest.    During the years ended December 31, 2012 and 2011, we recorded $0.4 million and $0.2 million, respectively, for the noncontrolling interest in the net income of DCEMB. The noncontrolling interest represents the 30% interest of our joint venture partner.

Fiscal Year Ended December 31, 2011 Compared to Fiscal Year Ended December 31, 2010

        Revenue.    Revenue increased by $80.9 million to $292.7 million in the year ended December 31, 2011, from $211.8 million in the year ended December 31, 2010. A portion of this increase was the result of an increase in the number of gallons delivered between periods from 122.7 million gasoline gallon equivalents to 155.6 million gasoline gallon equivalents. The increase in volume was primarily from an increase in CNG sales of 20.4 million gallons, and an increase in LNG sales of 13.2 million gallons. Our net increase in CNG volume was primarily from eight new stations for an existing refuse customer, six new stations for an existing transit customer, four new refuse customers, two new transit customers and one new airport customer, which together accounted for 14.2 million gallons of the CNG volume increase. We also experienced an increase of 16.9 million gallons in CNG volume between periods from our existing airport, transit and refuse customers, and volume growth from our share of our joint venture in Peru. These CNG volume increases were offset by a 10.2 million gallon decrease related to the loss of two transit customers. We also experienced a net increase of 13.2 million gallons in LNG volume between periods, which was primarily due to a 13.3 million gallon increase from Northstar O&M services in 2011. We experienced a slight decrease in our RNG sales (our 70% share of the RNG sales at DCE) of 0.7 million gallons as a result of adverse weather conditions which included a period of drought (which slows down gas flow) and a lightning strike that damaged some of our processing equipment. We experienced a $24.3 million increase, excluding Northstar, in station construction revenues between periods, primarily due to the completion of 12 new CNG stations for four refuse customers, four new CNG station upgrades for one of our existing transit customers, two new CNG stations for two transit customers, and one new CNG station for a trucking customer. Our acquisition of IMW on September 7, 2010 and Northstar on December 15, 2010 contributed $51.4 million and $9.8 million, respectively, to our increased revenue between periods. Revenue attributable to VETC also increased between periods as we recorded $17.9 million of revenue related to fuel tax credits in 2011, compared to $16.0 million in 2010. These increases were offset by the decrease in our effective price per gallon that we charged to our customers between periods. Our effective price per gallon charged was $0.86 for the year ended December 31, 2011, which represents a $0.13 per gallon decrease from $0.99 in the year ended December 31, 2010. The decrease was primarily due to a higher percentage of O&M contracts between periods, which generate less revenue per gallon than contracts where we supply the natural gas commodity. Revenue also decreased by $18.7 million between periods due to decreased sales of natural gas vehicle equipment by BAF.

        Cost of sales.    Cost of sales increased by $74.8 million to $216.7 million in the year ended December 31, 2011, from $141.9 million in the year ended December 31, 2010. Our cost of sales primarily increased between periods as a result of delivering more volume to our customers. Our acquisition of IMW on September 7, 2010 and Northstar on December 15 2010 contributed $48.7 million and $6.5 million, respectively, to our increased cost of sales between periods. We also experienced a $22.6 million increase, excluding Northstar, in station construction costs between periods. These increases were offset by the decrease in our effective cost per gallon of $0.08 per gallon, to $0.62 per gallon for 2011. This decrease was primarily the result of a higher percentage of O&M contracts in 2011 that are included in our volume totals but do not increase our cost of sales amount significantly as

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we do not pay for the natural gas consumed at the properties. We also experienced a $13.5 million decrease in costs related to BAF's vehicle equipment sales between periods as BAF's sales of natural gas vehicle equipment decreased between periods.

        Derivative (gain) loss on Series I warrant valuation.    Derivative gains decreased by $7.6 million to a gain of $2.7 million in the year ended December 31, 2011, from a gain of $10.3 million in the year ended December 31, 2010. 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 18 to our consolidated financial statements contained elsewhere herein.)

        Selling, general and administrative.    Selling, general and administrative expenses increased by $23.6 million to $86.9 million in the year ended December 31, 2011, from $63.3 million in the year ended December 31, 2010. The most significant increase was our salaries and benefits amount increasing by $15.6 million between periods as we increased our employee headcount from 710 at December 31, 2010 to 1,036 at December 31, 2011. Stock option expense also increased between periods by $1.6 million. In addition, consulting services increased $1.4 million, rent and occupancy increased $1.3 million, business insurance increased $1.2 million, and travel and entertainment increased $1.2 million between periods due to our business growth. These increases were offset by a $2.8 million gain related to a decrease in the estimated fair value of the BAF and IMW contingent consideration liabilities between periods. Also, 2010 included an impairment charge of $1.5 million related to an intangible asset as one of the contracts we acquired in 2009 was lost through a competitive bidding process, and a write-off of $0.7 million at our DCE subsidiary related to equipment that was replaced as part of the expansion of the McCommas Bluff landfill in Dallas, Texas. There were no impairments or write-offs in 2011.

        Depreciation and amortization.    Depreciation and amortization increased by $7.9 million to $30.4 million in the year ended December 31, 2011, from $22.5 million in the year ended December 31, 2010. This increase was primarily due to additional depreciation expense in 2011 related to increased property and equipment balances between periods, primarily related to our expanded station network. Our 2011 amortization expense also increased as 2011 includes a full year of amortization of the intangible assets we obtained in connection with our acquisition of IMW in the third quarter of 2010 and Northstar in the fourth quarter of 2010.

        Interest expense, net.    Interest expense, net, increased by $8.4 million to $9.6 million of expense for the year ended December 31, 2011, up from $1.2 million for the year ended December 31, 2010. This increase was primarily the result of an increase in interest expense related to the debt we incurred to acquire IMW in the third quarter of 2010, the $40.2 million bond issuance by our DCE subsidiary completed in March, 2011, and our $200 million of convertible notes we issued in July and August of 2011. (See note 9 to the consolidated financial statements for a full description of our outstanding debt).

        Other income (expense), net.    Other income (expense), net, decreased by $2.7 million to $0.6 million of expense for the year ended December 31, 2011, compared to income of $2.1 million for the year ended December 31, 2010. This decrease was primarily due to foreign currency exchange rate changes between periods on our IMW purchase notes.

        Income (loss) from equity method investment.    During 2011, we recorded $0.6 million of equity in the income of our 49% interest in our Peruvian joint venture, compared to $0.4 million in 2010.

        Loss (income) of noncontrolling interest.    During the year ended December 31, 2011, we recorded $0.2 million for the noncontrolling interest in the net income of DCE, compared to $0.3 million for the noncontrolling interest in the net loss of DCE in the year ended December 31, 2010. The noncontrolling interest represents the 30% interest of our joint venture partner.

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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 tends 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 and could affect our ability to maintain our stations adequately, build new stations, build new LNG plants and expand our existing facilities, or materially increase our operating costs.

Liquidity and Capital Resources

        We require cash to fund our operating expenses and working capital requirements, including outlays for the construction of new fueling stations, construction of LNG production facilities, the purchase of new LNG tanker trailers, investment in RNG production, 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 for our expansion. Our principal sources of liquidity are cash on hand and cash provided by financing activities.

Liquidity

        Cash used in operating activities was $19.8 million in 2012, compared to $27.1 million in 2011. The improvement in operating cash flow resulted primarily from changes in certain operating assets and liabilities. The net change was primarily driven by a reduction in prepaids and other assets, which was the result of the completion and sale of various construction projects in 2012 that were started in 2011, and our effort to maintain inventory levels during 2012 after increasing inventory levels in 2011 in anticipation of increased demand. The improvements in operating cash flow were offset by increased selling, general and administrative expenses and interest charges in 2012.

        Cash used in investing activities was $163.9 million in 2012, compared to $165.9 million in 2011. We purchased property and equipment for $192.9 million in 2012, which is an increase of $126.2 million from $66.7 million paid to purchase property and equipment in 2011. This increase is primarily related to our increased efforts in building the first phase of America's Natural Gas Highway during 2012. During 2011, our restricted cash increased by $57.1 million, primarily related to the closing of the DCEMB bond offering and the issuance of the first of three CHK Notes (as defined below) to Chesapeake during the period. During 2012, our restricted cash balances decreased by $37.9 million as we spent the majority of the 2011 restricted funds on various construction projects and a significant amount of the additional restricted funds we received in 2012 (primarily the second CHK Note) during the period on building America's Natural Gas Highway. We made additional investments in The Vehicle Production Group, LLC ("VPG"), a company producing a CNG taxi and a paratransit vehicle, during 2012 totaling $1.4 million, compared to $2.9 million during 2011. In 2011, we also invested $1.2 million in ServoTech and $0.6 million in our joint venture in Peru, and we also purchased Weaver Electric, Inc. for $1.0 million. The loans we made to our customers to assist them in purchasing natural gas vehicles increased to $10.5 million during 2012, up from $5.6 million in the prior year. During 2012 and 2011, we also collected on and sold $8.3 million and $2.5 million, respectively, of loans previously made to our customers. Additionally, we purchased a net amount of $5.6 million of short-term investments during 2012, compared to a net purchase of $33.3 million during 2011.

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        Cash provided by financing activities in 2012 was $53.6 million, compared to $377.8 million in 2011. In 2011, we raised $200.0 million from convertible debt securities that closed in July and August of 2011, and we raised $40.2 million from the DCEMB bond offering to fund the expansion of the landfill gas processing facility owned by DCEMB that closed on March 31, 2011. In 2012, we raised $50.0 million of convertible debt securities. In 2011 we paid $3.1 million of debt issuance costs related to the DCEMB bond offering. In 2011, we received $150.0 million in proceeds from Boone Pickens and other third-party investors when they exercised $150.0 million of warrants. In addition, there was an increase of $7.5 million in net proceeds that we received from the exercise of employee stock options between years. We also experienced a decrease of $7.0 million in repayment of capital lease obligations and debt instruments in 2012, primarily due to the fact that we paid off our Facility B loan on March 31, 2011 (see note 9 to our financial statements contained elsewhere herein).

        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 any outstanding indebtedness and the interest we are obligated to pay on this indebtedness, our capital expenditure requirements (which consist primarily of station construction, LNG plant construction costs, RNG plant construction costs and the purchase of LNG tanker trailers and equipment) and any merger or acquisition activity.

Sources of Cash

        Historically, our principal sources of liquidity have consisted of cash provided by operations and financing activities. At December 31, we had total cash and cash equivalents of $108.5 million, compared to $238.1 million at December 31, 2011.

        On July 11, 2011, we entered into a loan agreement with Chesapeake, an indirect wholly owned subsidiary of Chesapeake Energy Corporation, whereby Chesapeake agreed to purchase from us up to $150.0 million aggregate principal amount of debt securities for the development, construction and operation of LNG stations pursuant to the issuance of three convertible promissory notes, each having a principal amount of $50.0 million (collectively the "CHK Notes"). Chesapeake Energy Corporation guaranteed Chesapeake's commitment to purchase the CHK Notes under the loan agreement. The first $50 million convertible promissory note was issued on July 11, 2011, the second note was issued on July 10, 2012, and the third note is expected to be issued in June 2013.

        On August 30, 2011, we issued $150.0 million aggregate principal amount of debt securities to three institutional investors.

        On December 27, 2011, we received aggregate net proceeds of $150.0 million from the exercise of warrants by Boone Pickens and certain third party investors.

        On November 7, 2012, we, through two wholly owned subsidiaries (the "Borrowers"), entered into a 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 production facilities, each with an expected production capacity of approximately 250,000 LNG gallons per day.

Capital Expenditures

        Our business plan calls for approximately $186.2 million in capital expenditures in 2013, primarily related to construction of new fueling stations, including stations along ANGH, construction and expansion of our LNG plants, expansion and construction of landfill gas processing plants, and the purchase of LNG trailers. We may also elect to invest additional amounts in companies or assets in the natural gas fueling infrastructure, services and production industries, including RNG production. We will need to raise additional capital as necessary to fund any capital expenditures or investments that we cannot fund through available cash or cash generated by operations. The timing and necessity of

57

any future capital raise will depend on our rate of new station construction and potential merger or acquisition activity. We may not be able to raise capital on terms that are favorable to existing stockholders or at all. Any inability to raise capital may impair our ability to invest in new stations, develop natural gas fueling infrastructure and invest in strategic transactions or acquisitions and may reduce the ability of our business to grow and generate increased revenues.

Contractual Obligations

        The following represents the scheduled maturities of our contractual obligations as of December 31, 2012:

 
   Payments Due by Period  
Contractual Obligations:
  Total   Less than 1 year   1 - 3 years   3 - 5 years   More than 5 years  

Long-term debt and capital lease obligations(a)

   $ 421,367   $ 51,798   $ 59,904   $ 177,725   $ 131,940  

Operating lease commitments(b)

     37,899     5,617     10,628     9,698     11,956  

"Take or pay" LNG purchase contracts(c)

     17,925     5,153     7,165     5,607     —  

Construction contracts(d)

     107,746     107,746     —     —     —  

DCEMB electricity contract(e)

     4,796     1,647     3,149     —     —  
                       

Total

   $ 589,733   $ 171,961   $ 80,846   $ 193,030   $ 143,896  
                       
(a)
Consists of long-term debt and capital lease obligations to finance acquisitions and equipment purchases, including interest.

(b)
Consists of various space and ground leases for our California LNG plant, offices and fueling stations as well as leases for equipment.

(c)
The amounts in the table represent our estimates for our fixed LNG purchase commitments under two "take-or-pay" contracts.

(d)
Consists of our obligations to fund various fueling station construction projects, net of amounts funded through December 31, 2012, and excluding contractual commitments related to station sales contracts.

(e)
Consists of our obligations to purchase electricity at our RNG plant at the McCommas Bluff landfill in Dallas, Texas.

Off-Balance Sheet Arrangements

        At December 31, 2012, 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 $53.8 million,

    •
    two take-or-pay contracts for the purchase of LNG,

    •
    operating leases where we are the lessee,

    •
    operating leases where we are the lessor and owner of the equipment, and

    •
    firm commitments to sell CNG and LNG at fixed prices.

        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

58

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 two contracts that require us to purchase minimum volumes of LNG at index based prices. One contract expires in June 2014 and the other contract expires in October 2017.

        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 2018. 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 will provide.

        We are also the lessor in various leases with our customers, whereby our customers lease certain stations and equipment that we own.

Item 7A.    Quantitative and Qualitative Disclosures about Market Risk.

        In the ordinary course of business, we are exposed to various market risk factors, including changes in general economic conditions, domestic and foreign competition, commodity price risk and foreign currency exchange rates.

        Commodity Risk.    We are subject to market risk with respect to our sales of natural gas, which has 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 22% (or 32% excluding BAF, IMW and Northstar) of our cost of sales for 2011 and 16% (or 21% excluding BAF, IMW and Northstar) for 2012.

        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 its 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 account for these futures contracts in accordance with FASB authoritative guidance on derivatives. The accounting under this guidance for changes in the fair value of a derivative depends upon whether it has been specified in a hedging relationship and, further, on the type of hedging relationship. To qualify for designation in a hedging relationship, specific criteria must be met and appropriate documentation maintained.

        The fair value of the futures contracts we use is based on quoted prices in active exchange traded or over the counter markets, which are then discounted to reflect the time value of money for contracts applicable to future periods. The fair value of these futures contracts is continually subject to change due to market conditions. In an effort to mitigate the volatility in our earnings related to futures activities, our board of directors adopted a revised natural gas hedging policy which restricts our ability to purchase natural gas futures contracts and to offer fixed price sales contracts to our customers. We plan to structure prospective futures contracts so that they will be accounted for as cash flow hedges under the FASB guidance, but we cannot be certain they will qualify. For more information, please read "—Risk Management Activities" above.

59

        We have prepared a sensitivity analysis to estimate our exposure to market risk with respect to the futures contracts we hold as of December 31, 2012 to hedge the fixed price component of certain supply contracts. If the price of natural gas were to fluctuate (increase or decrease) by 10% from the price quoted on NYMEX on December 31, 2012 ($3.71 per Mcf), we could expect a corresponding fluctuation in the value of the contracts of approximately $0.05 million.

        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 income (loss) component of consolidated equity 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 $0.7 million of gains in 2012. During 2012, our primary exposure to foreign currency rates related to our Canadian operations that had certain outstanding notes 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 December 31, 2012, we would expect a corresponding fluctuation in the value of the assets and liabilities of approximately $0.1 million.

Quarterly Results of Operations

        The following table sets forth the Company's quarterly consolidated statements of operations data for the eight quarters ended December 31, 2012. The information for each quarter is unaudited and the Company has prepared them on the same basis as the audited consolidated financial statements appearing elsewhere in this Form 10-K. This information includes all adjustments that management considers necessary for the fair presentation of such data. The quarterly data should be read together with the Company's consolidated financial statements and related notes appearing elsewhere in this Form 10-K. The results of operations for any one quarter are not necessarily indicative of results for any future period.

Quarterly Financial Data (Unaudited)
(In thousands, except share data)

 
   For the Quarter Ended  
 
   March 31, 2011   June 30, 2011   September 30, 2011   December 31, 2011  

Revenue:

                          

Product revenues

   $ 58,532   $ 61,523   $ 64,237   $ 75,991  

Service revenues

     6,809     7,590     7,845     10,190  
                   

Total revenues

     65,341     69,113     72,082     86,181  

Operating expenses:

                          

Cost of sales:

                          

Product cost of sales

     43,850     46,888     48,853     61,317  

Service cost of sales

     3,154     3,536     3,901     5,185  

Derivative (gains) losses:

                          

Series I warrant valuation

     3,300     (4,835 )   (1,524 )   404  

Selling, general and administrative

     18,030     21,653     20,140     27,027  

Depreciation and amortization

     7,210     7,632     7,554     8,010  
                   

Total operating expenses

     75,544     74,874     78,924     101,943  
                   

60

 
   For the Quarter Ended  
 
   March 31, 2011   June 30, 2011   September 30, 2011   December 31, 2011  

Operating loss

     (10,203 )   (5,761 )   (6,842 )   (15,762 )

Interest expense, net

     (820 )   (1,506 )   (3,194 )   (4,096 )

Other income (expense), net

     601     187     (2,450 )   1,051  

Income from equity method investments

     211     164     99     163  
                   

Loss before income taxes

     (10,211 )   (6,916 )   (12,387 )   (18,644 )

Income tax (expense) benefit

     735     1,177     960     (2,169 )
                   

Net loss

     (9,476 )   (5,739 )   (11,427 )   (20,813 )

Loss (income) of noncontrolling interest

     (277 )   120     73     (94 )
                   

Net loss attributable to Clean Energy Fuels Corp. 

   $ (9,753 ) $ (5,619 ) $ (11,354 ) $ (20,907 )
                   

Basic loss per share

   $ (0.14 ) $ (0.08 ) $ (0.16 ) $ (0.29 )
                   

Fully diluted loss per share

   $ (0.14 ) $ (0.08 ) $ (0.16 ) $ (0.29 )
                   

 

 
   For the Quarter Ended  
 
   March 31, 2012   June 30, 2012   September 30, 2012   December 31, 2012  

Revenue:

                          

Product revenues

   $ 65,776   $ 57,705   $ 82,720   $ 87,576  

Service revenues

     7,858     12,137     8,739     11,497  
                   

Total revenues

     73,634     69,842     91,459     99,073  

Operating expenses:

                          

Cost of sales:

                          

Product cost of sales

     51,902     43,691     67,392     73,486  

Service cost of sales

     3,984     4,839     3,839     4,551  

Derivative (gains) losses:

                          

Series I warrant valuation

     13,506     (8,899 )   (5,692 )   (2,306 )

Selling, general and administrative

     24,850     27,916     30,557     34,653  

Depreciation and amortization

     8,144     8,907     9,047     10,163  
                   

Total operating expenses

     102,386     76,454     105,143     120,547  
                   

Operating loss

     (28,752 )   (6,612 )   (13,684 )   (21,474 )

Interest expense, net

     (3,702 )   (3,321 )   (4,314 )   (4,732 )

Other income (expense), net

     841     (1,177 )   1,914     (342 )

Impairment of cost method investment

     —     —     —     (14,544 )

Income from equity method investments

     91     72     152     16  
                   

Loss before income taxes

     (31,522 )   (11,038 )   (15,932 )   (41,076 )

Income tax expense

     (246 )   (172 )   (277 )   (599 )
                   

Net loss

     (31,768 )   (11,210 )   (16,209 )   (41,675 )

Income of noncontrolling interest

     (137 )   (84 )   (112 )   (60 )
                   

Net loss attributable to Clean Energy Fuels Corp. 

   $ (31,905 ) $ (11,294 ) $ (16,321 ) $ (41,735 )
                   

Basic loss per share

   $ (0.37 ) $ (0.13 ) $ (0.19 ) $ (0.46 )
                   

Fully diluted loss per share

   $ (0.37 ) $ (0.13 ) $ (0.19 ) $ (0.46 )
                   

61

Item 8.    Financial Statements and Supplementary Data.


INDEX TO FINANCIAL STATEMENTS

 
   Page

Consolidated Financial Statements

    

Report of Independent Registered Public Accounting Firm

   63

Consolidated Balance Sheets as of December 31, 2011 and 2012

   65

Consolidated Statements of Operations for the Years Ended December 31, 2010, 2011, and 2012

   66

Consolidated Statements of Comprehensive Income (Loss) for the Years Ended December 31, 2010, 2011, and 2012

   67

Consolidated Statements of Stockholders' Equity for the Years Ended December 31, 2010, 2011, and 2012

   68

Consolidated Statements of Cash Flows for the Years Ended December 31, 2010, 2011, and 2012

   69

Notes to Consolidated Financial Statements

   71

Financial Statement Schedule

    

Schedule II—Valuation and Qualifying Accounts

   114

62


 Report of Independent Registered Public Accounting Firm

The Board of Directors and Stockholders
Clean Energy Fuels Corp.:

        We have audited the accompanying consolidated balance sheets of Clean Energy Fuels Corp. (the Company) and subsidiaries as of December 31, 2011 and 2012, and the related consolidated statements of operations, comprehensive income (loss), stockholders' equity, and cash flows for each of the years in the three-year period ended December 31, 2012. In connection with our audits of the consolidated financial statements, we have also audited the related financial statement schedule. We also have audited the Company's internal control over financial reporting as of December 31, 2012, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on these consolidated financial statements and financial statement schedule and an opinion on the Company's internal control over financial reporting based on our audits.

        We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the consolidated financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

        A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

        Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

        In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Clean Energy Fuels Corp. and subsidiaries as of December 31, 2011 and 2012, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2012, in conformity with U.S. generally accepted

63

accounting principles. Also in our opinion, the related financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material aspects, the information set forth therein. Also, in our opinion, Clean Energy Fuels Corp. and subsidiaries maintained, in all material respects, effective internal control over financial reporting as of December 31, 2012, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

/s/ KPMG LLP

Los Angeles, California
February 28, 2013

64


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)

 
   December 31,  
 
   2011   2012  

Assets

  

Current assets:

              

Cash and cash equivalents

   $ 238,125   $ 108,522  

Restricted cash

     4,792     8,445  

Short-term investments

     33,329     38,175  

Accounts receivable, net of allowance for doubtful accounts of $712 and $905 as of December 31, 2011 and December 31, 2012, respectively

     56,455     57,594  

Other receivables

     19,601     17,808  

Inventory, net

     35,287     38,152  

Prepaid expenses and other current assets

     22,252     16,002  
           

Total current assets

     409,841     284,698  

Land, property and equipment, net

     257,463     428,177  

Restricted cash

     54,804     13,208  

Notes receivable and other long-term assets

     16,650     71,389  

Investments in other entities

     16,459     2,581  

Goodwill

     73,741     75,865  

Intangible assets, net

     102,103     99,282  
           

Total assets

   $ 931,061   $ 975,200  
           


Liabilities and Stockholders' Equity
 

Current liabilities:

              

Current portion of long-term debt and capital lease obligations

   $ 22,925   $ 30,389  

Accounts payable

     36,668     39,216  

Accrued liabilities

     28,255     30,794  

Deferred revenue

     9,621     13,521  
           

Total current liabilities

     97,469     113,920  

Long-term debt and capital lease obligations, less current portion

     266,497     300,636  

Other long-term liabilities

     22,687     14,014  
           

Total liabilities

     386,653     428,570  

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 149,000,000 shares; issued and outstanding 85,433,258 shares and 87,634,478 shares at December 31, 2011 and December 31, 2012, respectively

     9     9  

Additional paid-in capital

     741,650     837,367  

Accumulated deficit

     (199,559 )   (300,814 )

Accumulated other comprehensive loss

     (1,216 )   6,151  
           

Total Clean Energy Fuels Corp. stockholders' equity

     540,884     542,713  

Noncontrolling interest in subsidiary

     3,524     3,917  
           

Total stockholders' equity

     544,408     546,630  
           

Total liabilities and stockholders' equity

   $ 931,061   $ 975,200  
           

See accompanying notes to consolidated financial statements.

65


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except share and per share data)

 
   Years Ended December 31,  
 
   2010   2011   2012  

Revenue:

                    

Product revenues

   $ 189,836   $ 260,283   $ 293,777  

Service revenues

     21,998     32,434     40,231  
               

Total revenue

     211,834     292,717     334,008  

Operating expenses:

                    

Cost of sales:

                    

Product cost of sales

     132,911     200,908     236,471  

Service cost of sales

     8,978     15,776     17,213  

Derivative gains:

                    

Series I warrant valuation

     (10,278 )   (2,655 )   (3,391 )

Selling, general and administrative

     63,258     86,850     117,976  

Depreciation and amortization

     22,487     30,406     36,261  
               

Total operating expenses

     217,356     331,285     404,530  
               

Operating loss

     (5,522 )   (38,568 )   (70,522 )

Interest expense, net

     (1,194 )   (9,616 )   (16,069 )

Other income (expense), net

     2,080     (611 )   1,236  

Impairment of cost method investment

     —     —     (14,544 )

Income from equity method investments

     427     637     331  
               

Loss before income taxes

     (4,209 )   (48,158 )   (99,568 )

Income tax (expense) benefit

     1,436     703     (1,294 )
               

Net loss

     (2,773 )   (47,455 )   (100,862 )

Loss (income) of noncontrolling interest

     257     (178 )   (393 )
               

Net loss attributable to Clean Energy Fuels Corp. 

   $ (2,516 ) $ (47,633 ) $ (101,255 )
               

Loss per share:

                    

Basic and diluted

   $ (0.04 ) $ (0.68 ) $ (1.16 )
               

Weighted average common shares outstanding:

                    

Basic and diluted

     62,549,311     70,415,431     87,455,073  
               

   

See accompanying notes to consolidated financial statements.

66


 CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In thousands)

 
   Year Ended December 31, 2010   Year Ended December 31, 2011   Year Ended December 31, 2012  
 
   Clean Energy Fuels Corp   Noncontrolling Interest   Total   Clean Energy Fuels Corp   Noncontrolling Interest   Total   Clean Energy Fuels Corp   Noncontrolling Interest   Total  

Net income (loss)

   $ (2,516 ) $ (257 ) $ (2,773 ) $ (47,633 ) $ 178   $ (47,455 ) $ (101,255 ) $ 393   $ (100,862 )

Other comprehensive income, net of tax:

                                                        

Foreign currency translation adjustments

     (1,778 )   —     (1,778 )   2,101     —     2,101     4,030     —     4,030  

Foreign currency adjustments on intra-entity long-term investments

     —     —     —     (1,286 )   —     (1,286 )   1,218     —     1,218  

Unrealized losses on available-for sale securities

     —     —     —     (126 )   —     (126 )   (32 )   —     (32 )

Unrecognized gains (losses) on derivatives

     (4,231 )   —     (4,231 )   2,091     —     2,091     2,151     —     2,151  
                                       

Total other comprehensive income (loss), net of tax

     (6,009 )   —     (6,009 )   2,780     —     2,780     7,367     —     7,367  
                                       

Comprehensive income (loss)

   $ (8,525 ) $ (257 ) $ (8,782 ) $ (44,853 ) $ 178   $ (44,675 ) $ (93,888 ) $ 393   $ (93,495 )
                                       

See accompanying notes to consolidated financial statements.

67


 CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(In thousands, except share data)

 
   Common stock    
    
    
    
    
  
 
   Additional Paid-In Capital   Retained Earnings (Accumulated Deficit)   Accumulated Other Comprehensive Income (Loss)   Noncontrolling Interest in Subsidiary   Total Stockholders' Equity  
 
   Shares   Amount  

Balance, December 31, 2009

     59,840,151   $ 6   $ 424,581   $ (149,410 ) $ 2,013   $ 3,186   $ 280,376  

Issuance of common stock upon exercise of options

     1,118,827     —     11,049     —     —     —     11,049  

Issuance of common stock, net of offering costs

     3,450,000     —     42,562     —     —     —     42,562  

Issuance of common stock upon exercise of Series I warrants

     1,183,712     —     17,152     —     —     —     17,152  

Issuance of common stock upon business combinations

     4,017,408     1     61,938     —     —     —     61,939  

Stock-based compensation

     —     —     11,920     —     —     —     11,920  

Net loss

     —     —     —     (2,516 )   —     (257 )   (2,773 )

Unrealized loss on futures contracts

     —     —     —     —     (4,231 )   —     (4,231 )

Foreign currency translation adjustment

     —     —     —     —     (1,778 )   —     (1,778 )
                               

Balance, December 31, 2010

     69,610,098     7     569,202     (151,926 )   (3,996 )   2,929     416,216  

Issuance of common stock upon exercise of options

     221,234     —     1,477     —     —     —     1,477  

Issuance of common stock, net of offering costs

     601,926     —     7,500     —     —     —     7,500  

Issuance of common stock upon exercise of Boone Pickens warrants

     15,000,000     2     149,998     —     —     —     150,000  

Stock-based compensation

     —     —     13,473     —     —     —     13,473  

Non-controlling interest contribution

     —     —     —     —     —     417     417  

Net loss

     —     —     —     (47,633 )   —     178     (47,455 )

Unrealized gain on futures contracts

     —     —     —     —     2,091     —     2,091  

Unrealized loss on short-term investments available for sale

     —     —     —     —     (126 )   —     (126 )

Foreign currency translation adjustment

     —     —     —     —     815     —     815  
                               

Balance, December 31, 2011

     85,433,258     9     741,650     (199,559 )   (1,216 )   3,524     544,408  

Issuance of common stock upon exercise of options

     1,568,480     —     8,969     —     —     —     8,969  

Issuance of common stock, net of offering costs

     632,740     —     8,503     —     —     —     8,503  

Issuance of warrants in connection with the GE Credit Agreement

     —     —     56,158     —     —     —     56,158  

Stock-based compensation

     —     —     22,087     —     —     —     22,087  

Net loss

     —     —     —     (101,255 )   —     393     (100,862 )

Unrealized gain on futures contracts

     —     —     —     —     2,151     —     2,151  

Unrealized loss on short-term investments available for sale

     —     —     —     —     (32 )   —     (32 )

Foreign currency translation adjustment

     —     —     —     —     5,248     —     5,248  
                               

Balance, December 31, 2012

     87,634,478   $ 9   $ 837,367   $ (300,814 ) $ 6,151   $ 3,917   $ 546,630  
                               

See accompanying notes to consolidated financial statements.

68


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

 
   Years Ended December 31,  
 
   2010   2011   2012  

Cash flows from operating activities:

                    

Net loss

   $ (2,773 ) $ (47,455 ) $ (100,862 )

Adjustments to reconcile net loss to net cash provided by (used in) operating activities:

                    

Depreciation and amortization

     22,487     30,406     36,261  

Asset impairments

     2,248     —     14,544  

Provision for doubtful accounts and notes

     264     344     1,358  

Loss on disposal of assets

     181     —     —  

Derivative gain

     (10,278 )   (2,655 )   (3,391 )

Stock-based compensation expense

     11,920     13,473     22,087  

Amortization of debt issuance cost

     —     339     551  

Accretion of notes payable

     1,118     2,731     2,016  

Gain on contingent consideration for acquisitions

     (1,184 )   (2,828 )   (4,112 )

Changes in operating assets and liabilities, net of assets and liabilities acquired:

                    

Accounts and other receivables

     (32,679 )   (137 )   1,832  

Inventory

     (4,882 )   (14,782 )   (1,879 )

Margin deposits on futures contracts

     (3,706 )   2,981     3,000  

Prepaid expenses and other assets

     (851 )   (14,709 )   4,201  

Accounts payable

     (503 )   324     (328 )

Accrued expenses and other

     7,935     4,832     4,966  
               

Net cash used in operating activities

     (10,703 )   (27,136 )   (19,756 )

Cash flows from investing activities:

                    

Purchases of short-term investments

     —     (33,329 )   (55,062 )

Maturities of short-term investments

     —     —     49,504  

Purchases of property and equipment

     (40,828 )   (66,687 )   (192,894 )

Proceeds from sale of property and equipment

     282     —     —  

Loans made to customers

     (4,555 )   (5,591 )   (10,521 )

Payments on and proceeds from sales of loans receivable

     3,934     2,508     8,251  

Acquisitions, net of cash acquired

     (20,473 )   (1,000 )   269  

Investments in other entities

     (427 )   (4,712 )   (1,437 )

Restricted cash

     —     (57,096 )   37,943  
               

Net cash used in investing activities

     (62,067 )   (165,907 )   (163,947 )

Cash flows from financing activities:

                    

Proceeds from minority interest DCE equity contribution

     —     417     —  

Proceeds from exercise of warrants

     11,537     150,000     —  

Proceeds from issuance of common stock

     42,562     —     —  

Proceeds from the exercise of stock options

     11,049     1,477     8,969  

Proceeds from debt instruments

     200     244,455     50,612  

Proceeds from revolving line of credit

     12,665     53,595     39,164  

Repayment of borrowing under revolving line of credit

     (14,348 )   (49,589 )   (34,735 )

Repayment of capital lease obligations and debt instruments

     (1,050 )   (17,079 )   (10,040 )

Contingent consideration paid relating to business acquisitions          

     —     (2,394 )   (350 )

69


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Continued)

(In thousands)

 
   Years Ended December 31,  
 
   2010   2011   2012  

Payment for debt issuance costs

     —     (3,054 )   —  
               

Net cash provided by financing activities

     62,615     377,828     53,620  

Effect of exchange rates on cash and cash equivalents

     (1,738 )   (1,854 )   480  
               

Net increase (decrease) in cash and cash equivalents

     (11,893 )   182,931     (129,603 )

Cash and cash equivalents, beginning of year

     67,087     55,194     238,125  
               

Cash and cash equivalents, end of year

   $ 55,194   $ 238,125   $ 108,522  
               

Supplemental disclosure of cash flow information:

                    

Income taxes paid

   $ 222   $ 783   $ 1,160  
               

Interest paid, net of $434, $1,352, and $6,304 capitalized, respectively

   $ 2,251   $ 6,744   $ 13,994  
               

See accompanying notes to consolidated financial statements.

70


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(In thousands, except share and per share data)

(1) Summary of Significant Accounting Policies

The Company

        Clean Energy Fuels Corp., together with its majority and wholly owned subsidiaries (hereinafter collectively referred to as the "Company"), is engaged in the business of selling natural gas fueling solutions to its customers, primarily in the United States and Canada.

        Clean Energy has a broad customer base in a variety of markets, including trucking, airports, taxis, refuse and public transit. The Company, builds, operates, maintains or supplies approximately 348 natural gas fueling locations in thirty-two states within the United States, and in British Columbia and Ontario within Canada. The Company also generates revenue through operation and maintenance ("O&M") agreements with certain customers, through building and selling or leasing natural gas fueling stations to its customers, through manufacturing and servicing natural gas fueling compressors and related equipment, providing natural gas vehicle conversions, providing design and engineering services for natural gas engine systems, processing and selling renewable natural gas ("RNG"), and through financing its customers' vehicle purchases and selling tradable credits the Company generates by selling natural gas and RNG as a vehicle fuel, including credits ("LCFS Credits") under the California low carbon fuel standard.

Basis of Presentation

        The 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 in accordance with U.S. generally accepted accounting principles ("US GAAP"). All intercompany accounts and transactions have been eliminated in consolidation.

Use of Estimates

        The preparation of consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements and revenues and expenses recorded during the reporting period. Actual results could differ from those estimates. Current economic conditions may require the use of additional estimates and these estimates may be subject to a greater degree of uncertainty as a result of the uncertain economy.

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.

Fair Value of Financial Instruments

        The carrying values of the Company's financial instruments, including cash and cash equivalents, accounts and other receivables, notes receivable, accounts payable, accrued expenses and other current liabilities, capital lease obligations and notes payable approximate fair value.

71


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(1) Summary of Significant Accounting Policies (Continued)

Inventories

        Inventories are stated at the lower of cost or market value on a first-in, first out basis. Management's estimate of market value includes a provision for slow-moving or obsolete inventory based upon inventory on hand and forecasted demand.

        Inventories consisted of the following as of December 31, 2011 and 2012:

 
   2011   2012  

Raw materials and spare parts

   $ 30,177   $ 30,137  

Work in process

     2,310     5,835  

Finished goods

     2,800     2,180  
           

Total

   $ 35,287   $ 38,152  
           

Property and Equipment

        Property and equipment are recorded at cost. Depreciation and amortization are recognized over the estimated useful lives of the assets using the straight-line method. The estimated useful lives of depreciable assets are twenty years for LNG liquefaction plant assets, ten years for station equipment and LNG trailers, and three to seven years for all other depreciable assets. Leasehold improvements are amortized over the shorter of their estimated useful lives or related lease terms. Periodically, the Company receives grant funding to assist in the financing of natural gas fueling station construction. The Company records the grant proceeds as a reduction of the cost of the respective asset. Total grant proceeds received were approximately $831, $3,090, and $5,908 for the years ended December 31, 2010, 2011 and 2012, respectively.

Long-Lived Assets

        The Company reviews long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying value of an asset may not be recoverable. Recoverability of long-lived assets to be held and used is measured by a comparison of the carrying amount of an asset to future net undiscounted cash flows expected to be generated by the asset or asset group. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. Assets to be disposed of are reported at the lower of the carrying amount or the fair value less costs to sell.

        During the fourth quarter of 2010, the Company's majority-owned subsidiary, Dallas Clean Energy, LLC ("DCE"), recorded an impairment charge of $717 related to equipment that was replaced as part of its expansion of the McCommas Bluff landfill in Dallas, Texas.

Goodwill and Intangible Assets

        Goodwill represents the excess of costs incurred over the fair value of the net assets of acquired businesses. Goodwill and intangible assets acquired in a business combination and determined to have an indefinite useful life are not amortized. In 2011, the Company changed its annual impairment testing to October 1 of each year. Beginning on October 1, 2011, the Company performed its test for

72


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(1) Summary of Significant Accounting Policies (Continued)

Goodwill impairment under the amended guidance issued by the FASB in Accounting Standards Update ("ASU") 2011-08, Testing for Goodwill Impairment, issued in September 2011, which the Company chose to early adopt, effective October 1, 2011. Under the amended requirements of ASU 2011-08, an entity is not required to quantitatively determine a reporting unit's fair value, if it concludes, based upon a qualitative assessment, that it is not more likely than not that the reporting unit's fair value is less than its carrying amount. A qualitative assessment is an option available on an individual reporting unit basis and is an unconditional alternative to Step 1 of the goodwill impairment test. A reporting entity can choose to perform either Step 1 or a qualitative assessment in subsequent reporting periods. If the Company does conduct a Step 1 test, the Company looks at its projected future cash flows and its market capitalization for its respective operations. In these instances, to the extent the Company's projected future cash flows do not materialize as planned or its market capitalization decreases, the Company could be forced to take an impairment charge in future periods.

        Beginning on October 1, 2012, the Company performed its test for indefinite-lived intangible assets impairment under the amended guidance issued by the FASB in ASU 2012-02, Testing Indefinite-Lived Intangible Assets for Impairment, issued in July 2012, which the Company chose to early adopt, effective October 1, 2012. The amended requirements of ASU 2012-02 provided a similar framework for testing indefinite-lived intangible assets for impairment as the ASU 2011-08 does for testing goodwill for impairment.

        There were no impairment charges for goodwill or indefinite-lived intangible asset resulting from the October 1, 2011 or 2012 impairment testing, and no events have occurred subsequent to October 1, 2012 which indicates impairment may have occurred.

        Intangible assets with finite useful lives are amortized over their respective estimated useful lives using the straight-line method. The estimated useful lives of intangible assets with finite useful lives are two to 20 years for technology, one to 16 years for lease agreements, one to eight years for customer relationships, one to 10 years for acquired contracts, two to 20 years for trademarks and trade names, and three years for non-compete agreements. The intangible assets with finite useful lives are reviewed for impairment whenever events or changes in circumstances indicate that the carrying value of the asset may not be recoverable.

73


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(1) Summary of Significant Accounting Policies (Continued)

        During the fourth quarter of 2010, as a result of losing a competitive bid to a customer, the Company recorded an impairment charge of $1,531 related to an intangible asset. The Company's intangible assets as of December 31, 2011 and 2012 were as follows:

 
   2011   2012  

Technology

   $ 56,026   $ 57,595  

Lease agreements

     21,045     21,645  

Customer relationships

     21,590     23,334  

Acquired contracts

     13,075     13,075  

Trademark and tradenames

     7,400     7,400  

Non-compete agreements

     2,126     2,126  
           

Total intangible assets

     121,262     125,175  

Less accumulated amortization

     (19,757 )   (30,632 )

Foreign currency rate change

     598     4,739  
           

Net intangible assets

   $ 102,103   $ 99,282  
           

        Included above is a trademark of indefinite useful life with carrying value of $1,200 as of December 31, 2011 and 2012, respectively.

        Amortization expense for intangible assets was $5,915, $10,071, and $10,875 for the years ended December 31, 2010, 2011 and 2012, respectively. Estimated amortization expense for the five years succeeding the year ended December 31, 2012 is approximately $9,217, $8,838, $8,586, $8,504 and $7,733, respectively.

Warranty Liability

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

 
   December 31, 2011   December 31, 2012  

Warranty liability at beginning of year

   $ 2,338   $ 3,130  

Costs accrued for new warranty contracts and changes in estimates for pre-existing warranties

     3,208     3,733  

Service obligations honored

     (2,416 )   (4,198 )
           

Warranty liability at end of year

   $ 3,130   $ 2,665  
           

Asset Retirement Obligations

        The Company recognizes the fair value of a liability for an asset retirement obligation in the period in which the liability is incurred or becomes reasonably estimable and if there is a legal obligation to restore or remediate the property at the end of the asset life or at the end of the lease term. All of the Company's fueling and storage equipment is located above-ground. The liability

74


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(1) Summary of Significant Accounting Policies (Continued)

amounts are based upon future retirement cost estimates and incorporate many assumptions such as the costs to restore the property, future inflation rates, and the adjusted risk free rate of interest. When the liability is initially recorded, the Company capitalizes the cost by increasing the related property and equipment balance. Over time, the liability is increased and expense is recognized for the change in the present value of the obligation, and the initial capitalized cost is depreciated over the useful life of the asset.

        The following table summarizes the activity of the asset retirement obligation, of which $964 and $1,215 is included in other long-term liabilities, with the remaining current portion included in accrued liabilities, as of December 31, 2011 and 2012, respectively:

 
   2011   2012  

Beginning balance

   $ 1,128   $ 1,179  

Liabilities incurred

     8     74  

Liabilities settled

     (3 )   —  

Accretion expense

     46     60  
           

Ending balance

   $ 1,179   $ 1,313  
           

Revenue Recognition

        The Company recognizes revenue on gas sales and O&M services in accordance with US GAAP, which requires that four basic criteria must be met before revenue can be recognized: (i) persuasive evidence of an arrangement exists; (ii) delivery has occurred and title and the risks and rewards of ownership have been transferred to the customer or services have been rendered; (iii) the price is fixed or determinable; and (iv) collectability is reasonably assured. Applying these factors, the Company typically recognizes revenue from the sale of natural gas fuel at the time the fuel is dispensed or, in the case of LNG sales agreements, delivered to the customers' storage facilities. The Company recognizes revenue from O&M agreements as the related services are provided.

        In certain transactions with Clean Energy customers, the Company agrees to provide multiple products or services, including construction of a station, providing O&M to the station, and sale of fuel to the customer. The Company evaluates the separability of revenues based on FASB authoritative guidance, which provides a framework for establishing whether or not a particular arrangement with a customer has one or more revenue elements. In 2010, the Company elected to apply newly issued FASB authoritative guidance that allows it to use a combination of internal and external objective and reliable evidence to develop management's best estimate of the fair value of the contract elements. If the arrangement contains a lease, the Company uses the existing evidence of fair value to separate the lease from the other elements in the arrangement. The arrangement's consideration that is fixed or determinable is then allocated to each separate unit of accounting based on the estimated relative selling price of each deliverable, which is determined based on the historical data derived from the Company's stand alone projects. The revenue allocated to the construction of the station is recognized using the completed-contract method. The revenue allocated to the O&M and sale of fuel is recognized ratably over the term of the arrangement.

75


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(1) Summary of Significant Accounting Policies (Continued)

        The Company recognizes revenue related to its leasing activities in accordance with FASB authoritative guidance. The Company's existing station leases are sales-type leases, giving rise to profit at the delivery of the leased station. Unearned revenue is amortized into income over the life of the lease using the effective-interest method. For these arrangements, the Company recognizes gas sales and O&M service revenues as earned from the customer on a volume-delivered basis.

        The Company typically recognizes revenue on fueling station construction projects where it sells the station to the customer using the completed-contract method because the projects are short-term and the results of operations reported on the completed-contract basis would not vary materially from those resulting from the use of the percentage-of-completion method. The construction contract is considered to be substantially completed at the earlier of customer acceptance of the fueling station or the time when the fuel dispensing activities begin. When applicable, multi-station construction contracts are segmented into phases as negotiated with customers. Gross margin related to each phase is recognized at its substantial completion. IMW Industries, Ltd. ("IMW") and Wyoming Northstar Incorporated, Southstar, LLC, and M&S Rental LLC (collectively "Northstar") use the percentage-of-completion method of accounting to recognize revenue because their projects are small and they have been able to demonstrate that they can reasonably estimate costs to complete. In these circumstances, revenue is recognized based on costs incurred in relation to total estimated costs to be incurred for a project.

        The Company recognizes revenue on RNG sales and vehicle sales when it transfers title of the gas or vehicle to its customer.

Volumetric Excise Tax Credits ("VETC")

        The Company records its VETC credits as revenue as the credits are fully refundable and do not need to offset income tax liabilities to be received. VETC revenues for the years ended December 31, 2010 and 2011 were $16,042, and $17,889, respectively. During 2010, the legislation providing for VETC was reinstated in the fourth quarter of 2010 and made retroactive to January 1, 2010. The VETC legislation expired on December 31, 2011, but was made retroactive to January 1, 2012 and extended to December 31, 2013 in January 2013 (see note 19). Such credits for 2012 will be recognized in the first quarter of 2013.

LNG Transportation Costs

        The Company records the costs incurred to transport LNG to its customers in the line item cost of sales in the accompanying statements of operations.

Advertising Costs

        Advertising costs are expensed as incurred. Advertising costs amounted to $1,260, $1,559, and $1,340 for the years ended December 31, 2010, 2011 and 2012, respectively.

Stock-based Compensation

        The Company recognizes compensation expense for all stock-based payment arrangements, net of an estimated forfeiture rate, over the requisite service period of the award. For stock options, the

76


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(1) Summary of Significant Accounting Policies (Continued)

Company determines the grant date fair value using the Black-Scholes option-pricing model which requires the input of certain assumptions, including the expected life of the stock-based payment awards, stock price volatility and risk-free interest rates.

Foreign Currency Translation

        In accordance with FASB authoritative guidance, the Company uses the local currency as the functional currency of its foreign subsidiary. Accordingly, all assets and liabilities outside the United States are translated into U.S. dollars at the rate of exchange in effect at the balance sheet date. Revenue and expense items are translated at the weighted-average exchange rates prevailing during the period. Net foreign currency translation adjustments are recorded as accumulated other comprehensive income (loss) in stockholders' equity.

        Foreign currency transactions occur when there is a transaction denominated in other than the respective entity's functional currency. The Company records the changes in the exchange rate for these transactions in the consolidated statements of operations. For the fiscal years ended December 31, 2010, 2011 and 2012, foreign exchange transaction gains and (losses) were included in other income (expense) and were $1,902, $(596), and $678, respectively.

Income Taxes

        Income taxes are computed using the asset and liability method. Under this method, deferred income taxes are recognized by applying enacted statutory tax rates applicable to future years to differences between the tax bases and financial reporting amounts of existing assets and liabilities. Valuation allowances are established when it is more likely than not that such deferred tax assets will not be realized.

        The Company has a recognition threshold and a measurement attribute for the financial statement recognition and measurement of tax positions taken or expected to be taken in a tax return. For those benefits to be recognized, a tax position must be more likely than not to be sustained upon examination by taxing authorities based on the technical merits of the position. The amount recognized is measured as the largest amount of benefit that has a greater than 50 percent likelihood of being realized upon ultimate settlement. The Company recognizes potential accrued interest and penalties related to unrecognized tax benefit in income tax expense.

Net Loss Per Share

        Basic net loss per share is computed by dividing net loss attributable to Clean Energy by the weighted-average number of common shares and common shares issuable for little or no cash consideration outstanding during the period. Diluted net loss per share is computed by dividing net loss attributable to Clean Energy by the weighted-average number of common shares and common shares issuable for little or no cash consideration outstanding and potentially dilutive securities outstanding during the period. Potentially dilutive securities include stock options and warrants, in 2011 and 2012, convertible notes, and in 2012, restricted stock units. The dilutive effect of stock options and warrants is computed under the treasury stock method. Potentially dilutive securities are excluded from the computations of diluted net loss per share if their effect would be antidilutive. In 2012, 5,000,000 shares

77


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(1) Summary of Significant Accounting Policies (Continued)

of common stock related to the GE Warrant were included in the basic and dilutive net loss per share calculation.

        The following potentially dilutive securities have been excluded from the diluted net loss per share calculations because their effect would have been antidilutive:

 
   2010   2011   2012  

Stock options

     10,433,551     10,683,303     12,083,677  

Warrants

     17,130,682     2,130,682     2,130,682  

Convertibles notes

     —     13,164,557     16,262,226  

Restricted stock units

     —     —     1,545,000  

Derivative Financial Instruments

        The Company, in an effort to manage its natural gas commodity price risk exposures related to certain contracts, utilizes derivative financial instruments. The Company, from time to time, enters into natural gas futures contracts that are over-the-counter swap transactions that convert its index-based gas supply arrangements to fixed price arrangements. The Company accounts for its derivative instruments in accordance with FASB authoritative guidance for derivative instruments and hedging activities, which requires the recognition of all derivatives as either assets or liabilities in the consolidated balance sheet and the measurement of those instruments at fair value.

        The Company's futures contracts at December 31, 2012 are being accounted for as cash flow hedges and are being used to mitigate the Company's exposure to changes in the price of natural gas and not for speculative purposes. At December 31, 2012, all of the Company's futures contracts qualified for hedge accounting.

        The counter-party to the Company's derivative transactions is a high credit quality counterparty; however, the Company is subject to counterparty credit risk to the extent the counterparty to the derivatives is unable to meet its settlement commitments. The Company manages this credit risk by minimizing the number and size of its derivative contracts. The Company actively monitors the creditworthiness of its counterparties and records valuation adjustments against the derivative assets to reflect counterparty risk, if necessary. The counter-party is also exposed to credit risk of the Company, which requires the Company to provide cash deposits as collateral.

Comprehensive Income (Loss)

        Comprehensive income (loss) is defined as the change in equity (net assets) of a business enterprise during the period from transactions and other events and circumstances from non-owner sources. The difference between net income and comprehensive income for the years ended December 31, 2010, 2011, and 2012 was primarily comprised of the Company's foreign currency translation adjustments and unrealized gains (losses) on futures contracts.

Concentration of Credit Risk

        Credit is extended to all customers based on financial condition, and collateral is generally not required. Concentrations of credit risk with respect to trade receivables are limited because of the large

78


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(1) Summary of Significant Accounting Policies (Continued)

number of customers comprising the Company's customer base and dispersion across many different industries and geographies. However, certain international customers have historically been slower to pay on trade receivables. Accordingly, the Company continuously monitors collections and payments from its customers and maintains a provision for estimated credit losses based upon its historical experience and any specific customer collection issues that it has identified. In addition, through Export Development Canada, IMW maintains accounts receivable insurance on a substantial portion of its foreign trade receivables, which covers up to 90% of the related outstanding balance. Although such credit losses have historically been within the Company's expectations and the provisions established, the Company cannot guarantee that it will continue to experience the same credit loss rates that it has in the past.

Recently Adopted Accounting Changes and Recently Issued and Adopted Accounting Standards

        On January 1, 2012, the Company adopted changes issued by the FASB to conform existing guidance regarding fair value measurement and disclosure between GAAP and International Financial Reporting Standards. These changes both clarify the FASB's intent about the application of existing fair value measurement and disclosure requirements and amend certain principles or requirements for measuring fair value or for disclosing information about fair value measurements. The clarifying changes relate to the application of the highest and best use and valuation premise concepts, measuring the fair value of an instrument classified in a reporting entity's shareholders' equity, and disclosure of quantitative information about unobservable inputs used for Level 3 fair value measurements. The amendments relate to measuring the fair value of financial instruments that are managed within a portfolio, application of premiums and discounts in a fair value measurement, and additional disclosures concerning the valuation processes used and sensitivity of the fair value measurement to changes in unobservable inputs for those items categorized as Level 3, a reporting entity's use of a nonfinancial asset in a way that differs from the asset's highest and best use, and the categorization by level in the fair value hierarchy for items required to be measured at fair value for disclosure purposes only. Other than the additional disclosure requirements (see note 18), the adoption of these changes had no impact on the consolidated financial statements.

        On January 1, 2012, the Company adopted changes issued by the FASB to the presentation of comprehensive income. These changes give an entity the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. The option to present components of other comprehensive income as part of the statement of changes in stockholders' equity was eliminated. The items that must be reported in other comprehensive income or when an item of other comprehensive income must be reclassified to net income were not changed. Additionally, no changes were made to the calculation and presentation of earnings per share. Management elected to present the two-statement option. Other than the change in presentation, the adoption of these changes had no impact on the consolidated financial statements.

        On October 1, 2012, the Company early adopted ASU 2012-02, Intangibles—Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment. The update simplifies the guidance for testing the decline in the realizable value (impairment) of indefinite-lived intangible assets other than goodwill. The new guidance allows an entity the option to first assess qualitative factors to

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(1) Summary of Significant Accounting Policies (Continued)

determine whether it is necessary to perform the quantitative impairment test. An entity electing to perform a qualitative assessment is no longer required to calculate the fair value of an indefinite-lived intangible asset unless the entity determines, based on a qualitative assessment, that it is more likely than not that the asset is impaired. The adoption of these changes had no impact on the consolidated financial statements.

        On October 1, 2012, the FASB issued ASU 2012-04, Technical Corrections and Improvements. The amendments represent changes to clarify the Accounting Standards Codification (ASC), correct unintended application of guidance, or make minor improvements to the ASC that are not expected to have a significant effect on current accounting practice. The Company does not expect the adoption of these changes to have a material impact on its consolidated financial statements.

(2) Acquisitions

Natural Gas Fueling Compressors

        On September 7, 2010, the Company, acting through certain of its subsidiaries, completed its purchase of the advanced natural gas fueling compressor and related equipment manufacturing and servicing business of IMW. IMW manufactures and services advanced, non-lubricated natural gas fueling compressors and related equipment for the global natural gas fueling market. IMW is headquartered near Vancouver, British Columbia, and has other manufacturing facilities near Shanghai, China and in Ferndale, Washington, and has sales and service offices in Bangladesh, Colombia, Peru and the United States.

        In connection with the closing of the Company's acquisition of IMW, a subsidiary of the Company (the "Acquisition Subsidiary") paid an upfront cash payment of $15,034 and issued 4,017,408 shares of the Company's common stock at closing to IMW's shareholder. The issued shares were registered and available for immediate resale by the IMW shareholder. An additional $288 was paid by the Acquisition Subsidiary when the Chinese regulatory authorities subsequently approved the transfer of IMW Compressors (Shanghai) Co. Ltd. to the Acquisition Subsidiary. The Acquisition Subsidiary also issued the following promissory notes, as amended on February 1, 2011, to the IMW shareholder (collectively, the "IMW Notes"): (i) a promissory note with a principal amount of $12,500 that was paid on January 31, 2011, (ii) a promissory note with a principal amount of CAD$5,000 and $7,500 that was paid in 2012, (iii) a promissory note with a principal amount of CAD$5,000 and $7,500 that was paid on February 7, 2013, and (iv) a promissory note with a principal amount of CAD$5,000 and $7,500 that is due and payable on January 31, 2014. The Company can pay $7,500 of each IMW Note in cash and/or shares of the Company's common stock (the exact combination of cash and/or stock to be determined at the Company's option). In addition, pursuant to a security agreement executed at closing, the IMW Notes are secured by a subordinate security interest in IMW.

        IMW's former shareholder may also receive additional contingent consideration based on future gross profits earned by IMW over the four year period following the acquisition. The additional contingent consideration is subject to achieving minimum gross profit targets and will be determined based on a sliding scale that increases at certain gross profit levels. During the four-year period during which these earn-out payments may be made, the former shareholder of IMW will receive between zero and 23% of the gross profit of IMW as additional consideration, up to a maximum of $40,000 in

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(2) Acquisitions (Continued)

the aggregate (which maximum would be payable if IMW achieves approximately $174,000 in gross profit over the four-year period during which these earn-out payments may be made). The IMW shareholder earned $235 for the first contingent consideration payment in 2011 and $350 for the second contingent consideration payment in 2012.

        The Company accounted for this acquisition in accordance with 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 fair value of the assets acquired and liabilities assumed:

Current assets

   $ 27,149  

Property, plant and equipment

     2,559  

Identifiable intangible assets

     81,400  

Goodwill

     45,049  
       

Total assets acquired

     156,157  

Liabilities assumed

     (25,986 )
       

Total purchase price

   $ 130,171  
       

        Management allocated approximately $81,400 of the purchase price to the identifiable intangible assets related to technology, customer relationships, non-compete agreements, and trademarks that were acquired with the acquisition. The fair value of the identifiable intangible assets will be amortized on a straight-line basis over their estimated useful lives ranging from three to twenty years. In addition, management allocated $45,049 to goodwill as part of the acquisition and recorded a contingent liability of $9,300 related to the additional contingent consideration described above. Under FASB authoritative guidance, the Company is required to adjust the value of the contingent consideration for this acquisition in the statement of operations as the value of the obligation changes each reporting period. As of December 31, 2012, the fair value of the contingent consideration was approximately $1,516.

        The results of operations of IMW have been included in the Company's consolidated financial statements since September 7, 2010.

        The following table presents the Company's unaudited pro forma results of operations for the year ended December 31, 2010 as if the acquisition had occurred at on January 1, 2010. The pro forma financial data for the period presented includes adjustments for the following: (i) elimination of intercompany transactions (ii) recording the additional amortization expense from the identifiable intangible assets (iii) adjusting the estimated tax provision of the pro forma combined results; (iv) US GAAP conversion adjustments and (v) the issuance of the Company's common stock as part of the acquisition. The Company prepared the pro forma financial information for the combined entities

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(2) Acquisitions (Continued)

for comparative purposes only, and it is not indicative of what actual results would have been if the acquisition had taken place on January 1, 2010, or of future results.

 
   For the year ended
December 31, 2010 		 

Revenue

   $ 249,093  

Net (loss)

     (7,922 )

(Loss) per share:

        

Basic and diluted

   $ (0.12 )

        For the period from September 7, 2010 through December 31, 2010, IMW contributed approximately $17,795 and $319, respectively, to the Company's revenue and net loss.

Liquefied Natural Gas Station Construction

        On December 15, 2010, the Company acquired Northstar, a leading provider of design, engineering, construction and maintenance services for LNG and liquefied to compressed ("LCNG") fueling stations. The purchase price primarily consisted of a closing cash payment in the amount of $7,414. The remaining consideration consists of five annual payments in the amount of $700 each commencing on the first anniversary of the closing date, and up to $4,000 in retention bonuses to certain key employees to be paid in four annual installments commencing on the first anniversary of the closing date.

        The following table summarizes the estimated fair values of the assets acquired and liabilities assumed as of December 15, 2010:

Current assets

   $ 4,434  

Property, plant and equipment

     941  

Identifiable intangible assets

     3,350  

Goodwill

     5,228  
       

Total assets acquired

     13,953  

Liabilities assumed

     (3,648 )
       

Total purchase price

   $ 10,305  
       

        Management allocated $2,250 of the purchase price to the identifiable intangible assets related to non-compete agreements, customer relationships, and backlog. The fair value of these identifiable intangibles will be amortized on a straight-line basis over their estimated useful lives ranging from one to ten years. The Company also allocated $1,100 of the purchase price to trademarks, which management believes has an indefinite useful life. In addition, management allocated $5,228 to goodwill as part of the acquisition.

        The results of Northstar's operations have been included in the Company's consolidated financial statements since December 15, 2010. Pro forma financial information has been excluded as Northstar's historical results of operation are immaterial to that of the Company.

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(2) Acquisitions (Continued)

Operating and Maintenance Contracts

        In May and June 2009, the Company acquired four compressed natural gas operations and maintenance services contracts for $5,645 in cash. The Company recorded $537 to tangible assets and $5,108 of intangible assets related to customer relationships, which are being amortized over their expected lives of eight years. The results of operations of the acquired contracts are included in the Company's consolidated financial statements from their acquisition dates forward, which are May 2009 for two of the contracts and June 2009 for the remaining two contracts. In addition, as part of the acquisition, the Company became the custodian of certain customer-owned inventories that it is required to replenish when the contracts expire. The customer-owned inventory was valued by the Company's as an asset at $986 with a corresponding balance of $986 recorded as a liability on the acquisition dates of the contracts. During 2010, the Company recorded a charge of $1,531 related to the impairment of an intangible asset originally recorded with this acquisition.

Vehicle Conversion

        On October 1, 2009, the Company purchased all the outstanding shares of BAF Technologies, Inc. ("BAF") under a stock purchase agreement for a total purchase price of $11,567, consisting of cash of $4,717, forgiveness of debt of $3,790, and net liabilities assumed of $3,060. BAF shareholders earned additional consideration of $2,159 in 2011 because BAF had achieved certain gross profit targets in 2010. The BAF shareholders did not receive any additional consideration for 2011, which was the end of the contingent consideration period.

        The Company allocated approximately $10,660 of the purchase price to the identifiable intangible assets related to customer relationships, engine certifications and trademarks that were acquired with the acquisition. The fair values of the identifiable intangible assets are being amortized on a straight-line basis over their estimated useful lives of 1.5 to 8 years. In addition, the Company allocated $774 to goodwill as part of the acquisition.

        On February 25, 2011 (the "Closing Date"), the Company paid $1,200 for a 19.9% interest in ServoTech Engineering, Inc. ("ServoTech"), a company that provides, among other services, design and engineering services for natural gas fueling systems. In connection with the investment, the Company was granted an option to purchase the remaining 80.1% of ServoTech for $2,800 (the "Exercise Price") during the 15 month period following the Closing Date (the "Purchase Option"). On April 30, 2012, the Company exercised the Purchase Option, paid 50% of the Exercise Price, or $1,400, in cash on that date, and paid the remaining $1,400 of the Exercise Price in cash on October 31, 2012. Through April 30, 2012, the Company accounted for its interest in ServoTech using the equity method of accounting as the Company had the ability to exercise significant influence over ServoTech's operations.

        The Company accounted for this acquisition in accordance with the authoritative guidance for business combinations in stages. The Company re-measured its previously held equity interest in ServoTech at fair value as of April 30, 2012 (the acquisition date) resulting in no gain or loss, and recognized the assets acquired and the liabilities assumed, measured at their fair values, as of the date

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(2) Acquisitions (Continued)

of acquisition. The following table summarizes the estimated fair values of the assets acquired and liabilities assumed as of the acquisition date:

Current assets

   $ 2,655  

Property & equipment

     239  

Identifiable intangible assets

     3,913  
       

Total assets acquired

     6,807  

Current liabilities assumed

     (2,807 )
       

Total purchase price

   $ 4,000  
       

        The Company identified intangible assets with estimated fair value of $3,913 related to certain customer contracts, the facility lease, and technology. The fair value of the identified intangible assets will be amortized on a straight-line basis over their estimated useful lives, ranging from two to seven years.

        The results of ServoTech's operations have been included in the Company's consolidated financial statements since April 30, 2012. The historical results of ServoTech's operations were not material to the Company's financial position or historical results of operations.

(3) Restricted Cash

        The Company classifies restricted cash as 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, 2011 and 2012:

 
   December 31, 2011   December 31, 2012  

Short-term restricted cash

              

Standby letters of credit

   $ 1,237   $ 669  

DCEMB bonds—current operating costs

     3,555     7,776  
           

Total short-term restricted cash

     4,792     8,445  

Chesapeake loan

     40,322     12,256  

DCEMB bonds—long-term plant expansion

     14,482     952  
           

Total restricted cash

   $ 59,596   $ 21,653  
           

(4) 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.

        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

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(4) Investments (Continued)

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 December 31, 2012 the Company believes its cost bases for its available-for-sale investments are properly recorded.

        Short-term investments as of December 31, 2011 are summarized as follows:

 
   Amortized Cost   Gross Unrealized Losses   Estimated Fair Value  

Municipal bonds & notes

   $ 19,703   $ (114 ) $ 19,589  

Zero coupon bonds

     712     —     712  

Corporate bonds

     3,040     (12 )   3,028  
               

Total available-for-sale securities

     23,455     (126 )   23,329  

Certificate of deposits

     10,000     —     10,000  
               

Total short-term investments

   $ 33,455   $ (126 ) $ 33,329  
               

        Short-term investments as of December 31, 2012 are summarized as follows:

 
   Amortized Cost   Gross Unrealized Losses   Estimated Fair Value  

Municipal bonds & notes

   $ 23,755   $ (105 ) $ 23,650  

Corporate bonds

     4,557     (53 )   4,504  
               

Total available-for-sale securities

     28,312     (158 )   28,154  

Certificate of deposits

     10,021     —     10,021  
               

Total short-term investments

   $ 38,333   $ (158 ) $ 38,175  
               

(5) Other Receivables

        Other receivables at December 31, 2011 and 2012 consisted of the following:

 
   2011   2012  

Loans to customers to finance vehicle purchases

   $ 1,789   $ 4,151  

Capital lease receivables

     310     308  

Accrued customer billings

     5,860     6,934  

Fuel tax credits

     5,912     2,780  

Other

     5,730     3,635  
           

  $ 19,601   $ 17,808  
           

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(6) Land, Property and Equipment

        Land, property and equipment at December 31, 2011 and 2012 are summarized as follows:

 
   2011   2012  

Land

   $ 1,198   $ 1,476  

LNG liquefaction plants

     93,109     93,384  

RNG plants

     21,005     23,582  

Station equipment

     118,613     158,447  

LNG trailers

     13,532     13,566  

Other equipment

     26,508     47,143  

Construction in progress

     66,256     198,916  
           

    340,221     536,514  

Less accumulated depreciation

     (82,758 )   (108,337 )
           

  $ 257,463   $ 428,177  
           

        Included in the land, property and equipment are capitalized software costs of $5,539 and $17,611 as of December 31, 2011 and December 31, 2012, respectively. The accumulated amortization on the capitalized software costs is $3,568 and $5,380 as of December 31, 2011 and December 31, 2012, respectively. The Company recorded $498, $1,635, and $1,812 of amortization expense related to the capitalized software costs in 2010, 2011 and 2012, respectively.

        As of December 31, 2011 and 2012, $9,211 and $12,087 are included in accounts payable balances, respectively, which are related to purchases of property and equipment. These amounts are excluded from the consolidated statements of cash flows as they are non-cash investing activities.

(7) Investment in Other Entities

        The Company invested in The Vehicle Production Group LLC ("VPG"), a company that developed a natural gas vehicle made in the United States for taxi and paratransit use. The Company has accounted for its investment in VPG under the cost method of accounting as the Company has not had the ability to exercise significant influence over VPG's operations. Through June 2012, the Company invested an additional $1,437 in VPG. In the fourth quarter of 2012, the Company determined there was a decrease in value of its cost method investment in VPG that was other than temporary and accordingly recognized an impairment charge for the full value of its investment of $14,544.

        The Company has invested in Clean Energy del Peru ("Peru JV"), a joint venture in Lima, Peru that operates CNG stations. The Company accounts for its investment in Peru JV under the equity method of accounting as the Company has the ability to exercise significant influence over Peru JV's operations. At December 31, 2012, this investment had a balance of $2,581. The Company has agreed to sell its investment in Peru JV to its joint venture partner (see note 19).

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(8) Accrued Liabilities

        Accrued liabilities at December 31, 2011 and 2012 consisted of the following:

 
   2011   2012  

Salaries and wages

   $ 5,088   $ 4,558  

Accrued gas and equipment purchases

     4,773     10,091  

Derivative liability

     2,259     112  

Contingent consideration obligations

     378     70  

Accrued property and other taxes

     3,043     4,483  

Accrued professional fees

     875     1,310  

Accrued employee benefits

     1,431     2,607  

Accrued warranty liability

     3,130     2,665  

Other

     7,278     4,898  
           

  $ 28,255   $ 30,794  
           

(9) Long-term Debt

        In conjunction with the Company's acquisition of its 70% interest in Dallas Clean Energy, LLC ("DCE"), on August 15, 2008, the Company entered into a credit agreement ("Credit Agreement") with PlainsCapital Bank ("PCB"). The Company borrowed $18,000 (the "Facility A Loan") to finance the acquisition of its membership interests in DCE. The Company also obtained a $12,000 line of credit from PCB to finance capital improvements of the DCE processing facility and to pay certain costs and expenses related to the acquisition and the PCB loans (the "Facility B Loan").

        On October 7, 2009, the Facility A Loan was repaid in full and converted into a $20,000 line of credit (the "A Line of Credit") pursuant to an amendment to the Credit Agreement. On August 13, 2010, the Credit Agreement was amended to extend the maturity date of the A Line of Credit to August 14, 2011 and add an unused facility fee. The amendment also provided for a 1-year option to extend the maturity date to August 14, 2012, subject to the Company not being in default on the A Line of Credit. The unused facility fees are to be paid quarterly, in an amount equal to one-tenth of one percent (0.10%) of the unused portion. The Company elected not to renew the A Line of Credit on August 14, 2011 and the Line of Credit expired on that date. The principal amount of the Facility B Loan became due and payable in annual payments commencing on August 1, 2009, and continuing each anniversary date thereafter, with each such payment being in an amount equal to the lesser of twenty percent of the aggregate principal amount of the Facility B Loan then outstanding or $2,800. Pursuant to an amendment to the Facility B loan between the Company and PCB dated November 1, 2010, PCB agreed to forgo the scheduled payment due from the Company on August 2010 in the amount of $2,059 until January 31, 2011, which payment was made on such date. On March 31, 2011, the Company paid in full the remaining principal and interest that was due under the Facility B Loan.

        In conjunction with the DCE acquisition mentioned above, the Company also entered into a Loan Agreement with DCE (the "DCE Loan") to provide secured financing of up to $14,000 to DCE for future capital expenditures or other uses as agreed to by the Company, in its sole discretion. On March 31, 2011, the entire amount of unpaid principal and interest due under the DCE Loan was paid to the Company. The interest income related to the DCE Loan has been eliminated in the accompanying consolidated statements of operations.

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(9) Long-term Debt (Continued)

Revenue Bonds

        On March 25, 2011, the Company's 70% owned subsidiary, Dallas Clean Energy McCommas Bluff, LLC, a Delaware limited liability company ("DCEMB"), arranged for a $40,200 tax-exempt bond issuance (the "Revenue Bonds"). The Revenue Bonds will be repaid from the revenue generated by DCEMB from the sale of RNG. The Revenue Bonds are secured by the revenue and assets of DCEMB and are non-recourse to DCEMB's direct and indirect parent companies, including the Company. The bond repayments are amortized through December 2024 and the average coupon interest rate on the bonds is 6.60%. The bond issuance closed March 31, 2011.

        The bond proceeds will primarily be used to finance further improvements and expansion of the landfill gas processing facility owned by DCEMB at the McCommas Bluff landfill outside of Dallas, Texas. A portion of the proceeds were used to retire the DCE Loan discussed above. The Company, in turn, used the proceeds from the payoff of the DCE Loan to repay approximately $8,000 owed by the Company to PCB under the Facility B Loan on March 31, 2011.

        Pursuant to the Loan Agreement, dated as of January 1, 2011 (the "Loan Agreement"), between DCEMB and the Mission Economic Development Corporation (the "Issuer"), DCEMB has covenanted with the Issuer to make loan repayments equal to the principal and interest coming due on the Revenue Bonds. DCEMB executed a promissory note, dated March 31, 2011 (the "Note"), as evidence of its obligations under the Loan Agreement. Pursuant to the Trust Indenture, dated as of January 1, 2011 (the "Indenture"), the Issuer has pledged and assigned to the Trustee all of the Issuer's right, title and interest in and to the Loan Agreement (with certain specified exceptions) and the Note.

        The obligations of DCEMB under the Loan Agreement are secured by a Leasehold Deed of Trust, Assignment of Rents, Security Agreement and Fixture Filing, dated as of January 1, 2011 (the "Deed of Trust"), executed by DCEMB in favor of the deed of trust trustee named therein for the benefit of the Bank of New York Mellon Trust Company, N.A., as Trustee (the "Trustee"). In addition, DCEMB executed a Security Agreement (the "Security Agreement"), as security for its obligations, pursuant to which DCEMB granted to the Trustee a security interest in all right, title and interest of DCEMB to the Collateral (as defined in the Security Agreement), which includes, but is not limited to, DCEMB's rights, title and interest in any gas sale agreements, including the gas sale agreement with Shell Energy North America (US), L.P. (the "Shell Gas Sale Agreement"), and the funds and accounts held under the Indenture.

        Pursuant to a Consent and Agreement, by and between Shell Energy, The Bank of New York Mellon Trust Company, N.A., as Depository Bank (the "Depository Bank"), DCEMB and the Trustee, dated as of January 1, 2011 (the "Consent Agreement"), Shell Energy agreed to make all payments due to DCEMB under the Shell Gas Sale Agreement to the Depository Bank. In addition, other revenues generated through the sale of gas produced at the facility will be paid directly to the Depository Bank pursuant to a Depository and Control Agreement, dated as of January 1, 2011 (the "Depository Agreement"), among DCEMB, the Trustee and the Depository Bank.

        All payments received by the Depository Bank will be placed into various accounts in accordance with the requirements of the Indenture and the Depository Agreement. The funds in these accounts will be used to service required debt payments, finance further improvements and expansion of the landfill gas processing facility owned by DCEMB, finance the operations and maintenance of DCEMB,

88


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(9) Long-term Debt (Continued)

finance certain expenses associated with setting up and maintaining the accounts, and other uses as prescribed in the Depository Agreement. The Depository Bank will make payments out of these accounts in accordance with the requirements of the Depository Agreement. At the end of each month after all required account fundings have been fulfilled in accordance with the Depository Agreement, all remaining excess funds will be placed into a Surplus Account. The funds in the Surplus Account will be delivered to DCEMB so long as (i) DCEMB's Debt Service Coverage Ratio (as defined) for the most recent four calendar quarters then ended equals or exceeds 1.25:1, (ii) DCEMB's Debt Service Coverage Ratio (as defined) is reasonably projected to equal or exceed 1.25:1 for the next four calendar quarters, (iii) no events of default have occurred as defined by the Indenture and the Loan Agreement, and (iv) after giving effect to the transfer, DCEMB's Minimum Days Cash on Hand (as defined) shall be, or shall at any time be projected to be, more than the lesser of thirty-five Days Cash on Hand (as defined) or $1,300. Due to these restrictions on this cash, the Company has classified all of this cash as restricted cash on the balance sheet. The Company records the restricted cash that is expected to be received and used within the next 12 months from the Depository Bank for working capital and operating purposes as current in its balance sheet, and presents the remaining balance as non-current in the line item notes receivable and other long term assets. At December 31, 2012, $952 was recorded as long term restricted cash and $7,776 was recorded as short term restricted cash in the accompanying consolidated balance sheet.

        Pursuant to a Collateral Assignment and Consent Agreement with Atmos Pipeline—Texas ("Atmos"), DCEMB has collaterally assigned to the Trustee, subject to certain reserved rights and the consent of Atmos, the transportation agreements of the Company with Atmos.

        The Indenture and the Loan Agreement have certain non-financial debt covenants with which DCEMB must comply. As of December 31, 2012, DCEMB was in compliance with all its debt covenants.

Purchase Notes

        In connection with the closing of the Company's acquisition of IMW, the Company agreed to make future payments consisting of four annual payments in the amount of $12,500 which were subsequently amended to be CAD$5,000 and $7,500. Each payment under the IMW Notes will consist of CAD$5,000 in cash and $7,500 in cash and/or shares of the Company's common stock (the exact combination of cash and/or stock to be determined at the Company's option). In addition, pursuant to a security agreement executed at closing, the IMW Notes are secured by a subordinate security interest in IMW. In January 2011, the Company paid $5,000 in cash and $7,500 in shares of its common stock. The Company paid CAD$5,000 in cash in January 2012 and $3,750 in shares of its common stock in each of August 2012 and October 2012. The Company paid CAD$5,000 in cash and $7,500 in shares of its common stock in February 2013. The IMW Notes that were settled with shares of the Company's common stock are not included in the consolidated statements of cash flows as they are non-cash financing activities.

        In connection with the closing of the Company's acquisition of Northstar, the Company agreed to make future payments consisting of five annual payments in the amount of $700 each with the first payment due December 15, 2011. Each of the first two payments of $700 was paid in December 2011 and 2012, respectively.

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(9) Long-term Debt (Continued)

        In connection with the closing of the Company's acquisition of the natural gas fuel infrastructure construction business of Weaver Electric, Inc. on October 3, 2011, the Company paid $1,000 in cash and agreed to make four additional annual payments in the amount of $250 each with the first payment due October 3, 2012 (the "Weaver Notes"). In May 2012, the Company prepaid $125 of the October 2012 payment, and the remaining amount of such payment was paid in October 2012.

        In connection with the closing of the Company's acquisition of ServoTech on April 30, 2012, the Company paid $1,400 in cash at closing and paid an additional $1,400 in cash on October 31, 2012.

        The difference between the carrying amount and the face amount of these obligations is being accreted to interest expense over the remaining term of the obligations.

HSBC Lines of Credit

        In connection with the closing of the Company's acquisition of IMW, the Company entered into an Assumption Agreement (the "Assumption Agreement") with HSBC Bank Canada ("HSBC") pursuant to which the Company assumed the obligations and liabilities of IMW under the following arrangements with HSBC (collectively, the "IMW Lines of Credit"):

    (i)
    An operating line of credit with a limit of $13,000 in Canadian dollars ("CAD") to assist in financing the day-to-day working capital needs of IMW. The interest on amounts outstanding shall be payable at IMW's option at (a) HSBC's Prime Rate plus 1.00% per annum, (b) HSBC's U.S. Base Rate plus 1.00% per annum, or LIBOR plus 2.25% per annum, subject to availability.

    (ii)
    A demand revolving line of credit with a limit of CAD$2,000 bearing interest at the same rate as that of the operating line of credit discussed above, to assist in financing IMW's import requirements.

    (iii)
    A demand revolving bank guarantee and standby letter of credit line with a limit of CAD$1,115.

    (iv)
    A bank guarantee line with a limit of CAD$3,000, which allows IMW to provide guarantees and/or standby letters of credit to overseas suppliers or bid/performance deposits on contracts.

    (v)
    A forward exchange contract line with a limit of CAD$13,750 that allows IMW to enter into foreign exchange forward contracts up to the notional limit of CAD$13,750 (no forward exchange contracts were outstanding at December 31, 2012).

    (vii)
    An operating line of credit with a limit of 5,000 Renminbi ("RMB") (CAD$789) bearing interest at the 6 month People's Bank of China rate plus 2.5% and a sub-limit bank guarantee line of 5,000 RMB. The aggregate of the balances in the lines cannot exceed 5,000 RMB.

    (viii)
    A 16,750 Bengali Taka (CAD$209) operating line of credit bearing interest at 14%.

    (ix)
    A 170,000 Columbian Peso (CAD$95) operating line of credit bearing interest at the Colombia benchmark rate plus 7 to 12%.

        The IMW Lines of Credit are secured by a general security agreement providing a first priority security interest in all present and after acquired personal property of IMW, including specific charges on all serial numbered goods, inventory and other assets and assignment of risk insurance (the

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(9) Long-term Debt (Continued)

"Security"). The IMW Lines of Credit contain no fixed repayment terms or mandatory principal payments and are due on demand. Based on the relevant accounting guidance, the Company has classified this debt pursuant to the credit agreement as short-term given that it is due on demand.

        The Assumption Agreement with HSBC sets forth certain financial covenants with which IMW must comply, including: 1) its ratio of debt to tangible net worth must be no greater than 3.75 to 1.0 from January 1, 2012 through March 31, 2012, and no greater than 3.5 to 1.0 from April 1, 2012 through June 30, 2012, and no greater than 3.0 to 1.0 on or after July 1, 2012, 2) it must maintain a tangible net worth of at least CAD$7,000 and 3) its ratio of current assets to current liabilities may not be less than 1.15 to 1.0 until March 31, 2012 or less than 1.25 to 1.0 on or after April 1, 2012. IMW was in compliance with the financial covenants as of December 31, 2012.

        In addition, the Company and IMW agreed that should the making of any scheduled payment by IMW to the seller of IMW under the IMW Notes result in IMW being in breach of the Assumption Agreement, the IMW Lines of Credit or the Security, the Company shall furnish IMW with the funds needed to remain in compliance with the Assumption Agreement, the IMW Lines of Credit and the Security. Further, the Company and IMW agreed that should IMW make any future earn-out payments to the seller of IMW in connection with the acquisition of IMW, and should the making of such earn-out payments result in IMW being in breach of the Assumption Agreement, the IMW Lines of Credit or the Security, then the Company shall furnish IMW with the funds needed to make such earn-out payments and remain in compliance with the Assumption Agreement, the IMW Lines of Credit and the Security.

Chesapeake 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 for the development, construction and operation of liquefied natural gas stations (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"). Chesapeake Energy Corporation guaranteed Chesapeake's commitment to purchase the CHK Notes under the CHK Agreement.

        The first CHK Note was issued on July 11, 2011, the second CHK Note was issued on July 10, 2012 and the Company expects to issue the third CHK Note on or about June 28, 2013. The CHK Notes bear interest at the rate of 7.5% per annum (payable quarterly, in arrears, on March 31, June 30, September 30 and December 31 of each year) and are convertible at Chesapeake's option into shares of the Company's common stock at a conversion price of $15.80 per share (the "CHK Conversion Price"). Subject to certain restrictions, the Company can force conversion of each CHK Note into shares of the Company's common stock if, following the second anniversary of the issuance of a CHK Note, the Company's shares of common stock trade at a 40% premium to the CHK Conversion Price for at least 20 trading days in any consecutive 30 trading day period. The entire principal balance of each CHK Note is due and payable seven years following its issuance, and the Company may repay each CHK Note in shares of the Company's common stock or cash. The CHK Agreement restricts the use of the CHK Financing proceeds to financing the development, construction and operation of

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(9) Long-term Debt (Continued)

liquefied natural gas stations and payment of certain related expenses. At December 31, 2012, approximately $12,256 of these funds were included in long term restricted cash as the Company anticipates primarily using the funds to build LNG fueling stations. The CHK Agreement also provides for customary events of default which, if any of them occurs, would permit or require the principal of, and accrued interest on, the CHK Notes to become, or to be declared, due and payable.

        In connection with the CHK Financing, the Company also entered into a Registration Rights Agreement, dated July 11, 2011, with Chesapeake (the "CHK Registration Rights Agreement") pursuant to which the Company agreed, subject to the terms and conditions of the CHK Registration Rights Agreement, to (i) file with the Securities and Exchange Commission one or more registration statements relating to the resale of the Company's common stock issuable upon conversion of the CHK Notes, and (ii) at the request of Chesapeake, to participate in one or more underwritten offerings of the Company's common stock issuable upon conversion of the CHK Notes. If the Company does not meet certain of its obligations under the CHK Registration Rights Agreement with respect to the registration of the Company's common stock, it will be required to pay monthly liquidated damages of 0.75% of the principal amount of the CHK Note represented by the Company's common stock included (or to be included, as the case may be) in the applicable registration statement until the related obligation is met. As of December 31, 2012, the Company met its obligations under the CHK Registration Rights Agreement.

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 (payable quarterly, in arrears, on March 31, June 30, September 30 and December 31 of each year) 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"). Subject to certain restrictions, the Company can force conversion of each SLG Note into shares of the Company's common stock if, following the second anniversary of the issuance of the SLG Notes, the Company's shares of common stock 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 the Company's common stock or cash. The SLG 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 SLG Notes to become, or to be declared, due and payable. 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. Such

92


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(9) Long-term Debt (Continued)

conversion is not included in the consolidated statements of cash flows as it is a non-cash financing activity.

        In connection with the SLG Agreements, the Company also entered into a Registration Rights Agreement, dated August 30, 2011, with each of the Purchasers (the "SLG Registration Rights Agreements") pursuant to which the Company agreed, subject to the terms and conditions of the SLG Registration Rights Agreements, to (i) file with the Securities and Exchange Commission one or more registration statements relating to the resale of the Company's common stock issuable upon conversion of the SLG Notes, and (ii) at the request of the Purchasers, participate in one or more underwritten offerings of the Company's common stock issuable upon conversion of the SLG Notes. If the Company does not meet certain of its obligations under the SLG Registration Rights Agreements with respect to the registration of the Company's common stock, it will be required to pay monthly liquidated damages of 0.75% of the principal amount of the SLG Note represented by the Company's common stock included (or to be included, as the case may be) in the applicable registration statement until the related obligation is met, not to exceed 4% of the aggregate principal amount of the SLG Notes per annum. As of December 31, 2012, the Company met its obligations under the SLG Registration Rights Agreement.

GE Loans

        On November 7, 2012, the Company, through two wholly owned subsidiaries (the "Borrowers"), entered into a financing arrangement with General Electric ("GE Credit Agreement"). Pursuant to the GE Credit Agreement, GE Capital agreed to loan to the Borrowers up to an aggregate of $200,000 to finance the development, construction and operation of two LNG production facilities (individually a "Project" and together the "Projects"), each with an expected production capacity of approximately 250,000 LNG gallons per day. The Company expects to sell the LNG produced by the Projects through America's Natural Gas Highway, a nationwide network of LNG truck fueling stations, which the Company is building along major transportation corridors in the United States.

        The Borrowers' ability to obtain loans under the GE Credit Agreement (collectively, "Loans" and, with respect to each Project "Tranche A Loans" and "Tranche B Loans") for the Projects 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, (iii) commitment of all utility services necessary for the construction and operation of the Projects, and (iv) execution of an engineering, procurement and construction contract for each Project by the Company and GE Oil & Gas, Inc.

        The GE Credit Agreement further provides that (i) if initial Loans are not made prior to December 31, 2014, the GE Credit Agreement will automatically terminate, (ii) each Project must be completed by the earlier of (a) the date thirty months after the funding of the initial Loans with respect to such Project and (b) December 31, 2016 (with respect to each Project, the "Date Certain"), (iii) 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

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(9) Long-term Debt (Continued)

repaid by the applicable Date Certain, (iv) each Term Loan will be due and payable on the eighth anniversary of the Conversion Date with respect to such Term Loan, and (v) 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 GE Credit Agreement the then-current LIBOR rate will always be at least 1.00%. The GE Credit Agreement includes various customary covenants, including debt service coverage ratios, 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 December 31, 2012, the Company has not drawn any money under the GE Credit Agreement and was in compliance with the financial covenants.

        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 GE 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 Clean Energy to provide, concurrent with GE's extension of the initial Loans under the GE 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 GE Credit Agreement, the Company issued to GE a warrant to purchase up to 5,000,000 shares of the Company's common stock (see note 11).

        Long-term debt at December 31, 2011 and 2012 consisted of the following:

 
   December 31,
2011 		  December 31,
2012 		 

IMW Notes

   $ 34,400   $ 23,983  

Northstar future payments

     2,388     1,848  

DCEMB notes

     585     585  

DCEMB Revenue Bonds (non recourse to the Company)

     39,400     38,700  

CHK Notes

     50,000     100,000  

SLG Notes

     150,000     149,000  

Weaver Notes

     872     680  

IMW assumed debt

     6,657     12,661  

Capital lease obligations

     5,120     3,568  
           

Total debt and capital lease obligations

     289,422     331,025  

Less amounts due within one year and short-term borrowings

     (22,925 )   (30,389 )
           

Total long-term debt and capital lease obligations

   $ 266,497   $ 300,636  
           

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(9) Long-term Debt (Continued)

        The following is a summary of aggregate maturities of long-term debt for each of the years ending December 31:

 
   2013   2014   2015   2016   2017   Thereafter  

IMW Notes

   $ 12,448   $ 11,535   $ —   $ —   $ —   $ —  

Northstar future payments

     662     617     569     —     —     —  

DCEMB notes

     585     —     —     —     —     —  

DCEMB Revenue Bonds

     2,200     2,415     2,540     2,675     2,830     26,040  

CHK Notes

     —     —     —     —     —     100,000  

SLG Notes

     —     —     —     149,000     —     —  

Weaver Notes

     241     227     212     —     —     —  

IMW assumed debt

     12,361     300     —     —     —     —  

Capital lease obligations

     1,892     1,157     395     34     35     55  
                           

Total

   $ 30,389   $ 16,251   $ 3,716   $ 151,709   $ 2,865   $ 126,095  
                           

(10) Derivative Transactions

        The Company marks to market its open futures positions at the end of each period and records the net unrealized gain or loss during the period in derivative (gains) losses in the consolidated statements of operations or in accumulated other comprehensive income in the consolidated balance sheets in accordance with the applicable accounting guidance. In the years ended December 31, 2010, 2011, and 2012, the Company recorded unrealized (gains) losses of 4,231, ($2,091), and $(2,151) in other comprehensive income (loss) related to its futures contracts. Of the Company's net futures contracts liability of $107 at December 31, 2012, $5 was recorded as an asset in prepaid expenses and other current assets and a liability of $112 was recorded in accrued liabilities in the Company's consolidated balance sheet as of December 31, 2012. Of the $2,355 liability for the Company's futures contracts at December 31, 2011, $2,259 is included in accrued liabilities for the short-term amount, and $96 is included in other long-term liabilities for the long-term amount in the Company's consolidated balance sheet as of December 31, 2011. The Company's ineffectiveness related to its futures contracts in the years ended December 31, 2011 and 2012 was insignificant. During the years ended December 31, 2010, 2011 and 2012, the Company recognized a loss of $1,781, $3,332 and $2,370, respectively, in cost of sales in the accompanying consolidated statement of operations related to its futures contracts that were settled during the respective years. These amounts were reclassified from accumulated other comprehensive income (loss). As of December 31, 2012, the remaining unrecognized loss of $107 is recorded as a component of accumulated other comprehensive income (loss). The Company expects to reclassify such unrecognized loss from accumulated other comprehensive income (loss) as cost of sales through June 30, 2013.

95


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(10) Derivative Transactions (Continued)

        The following table presents the notional amounts and weighted average fixed prices per gasoline gallon equivalent of the Company's natural gas futures contracts as of December 31, 2012:

 
   Gallons   Weighted
Average Price
Per Gasoline
Gallon
Equivalent 		 

2013

     1,140,000   $ 0.53  

(11) Stockholders' Equity

Authorized Shares

        The Company's certificate of incorporation authorizes the issuance of two classes of capital stock designated as common stock and preferred stock, each having $0.0001 par value per share. As of December 31, 2012, the Company was authorized to issue 150,000,000 shares, of which 149,000,000 shares are designated common stock and 1,000,000 shares are designated preferred stock.

Dividend Provisions

        The Company did not declare nor pay any dividends during the years ended December 31, 2010, 2011 or 2012.

Voting Rights

        Each holder of common stock has the right to one vote per share owned on matters presented for stockholder action.

Issuance of Common Stock

        On November 11, 2010, the Company issued 3,450,000 shares of common stock at a price of $13.25 per share, including 50,068 shares purchased by key executives of the Company, and the exercise in full by the underwriters of their option to purchase 450,000 additional shares of the Company's common stock. The purchase price paid by the key executives of the Company was $14.48 per share, which was the consolidated closing bid price of the Company's common stock on the NASDAQ Global Market on November 10, 2010. The Company received aggregate net proceeds of $42,562 after deducting underwriting discounts and commissions and offering expenses payable by the Company.

Issuance of Common Stock and Warrants

        On October 28, 2008, the Company entered into a Placement Agent Agreement (the "Placement Agent Agreement") relating to the sale and issuance by the Company to select investors of 4,419,192 units (the "Units"), with each Unit consisting of (i) one share of the Company's common stock, par value $0.0001 per share, (ii) a warrant to purchase 0.75 shares of Common Stock (the "Series I Warrant"), and (iii) one warrant to purchase up to 0.2571 shares of Common Stock (the "Series II Warrant"). The price of each Unit was $7.92 per Unit. The transaction closed on November 3, 2008, and the Company issued 4,419,192 shares of common stock, Series I Warrants to purchase up to 3,314,394 shares of Common Stock, and Series II Warrants to purchase up to 1,136,364 shares of

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(11) Stockholders' Equity (Continued)

Common Stock. The Company received approximately $32,484 after deducting the placement agent's fees and other offering expenses related to the Unit sale. The proceeds of $32,484 were allocated between the common stock, the Series I Warrants and the Series II Warrants. The Company allocated $19,166, $9,745 and $3,573 to the common stock, the Series I Warrants and the Series II Warrants, respectively.

        The Series I Warrants became exercisable beginning six months from the date of issuance for a period of seven years from the date they become exercisable, and carry an exercise price of $12.68 per share. On November 10, 2010, the Company entered into an amendment with one of the holders of the Series I warrants pursuant to which the expiration date of such warrant for the purchase of 1,183,712 shares of common stock was changed to November 10, 2010. In consideration of the modification to the expiration date, the Company agreed to pay the holder of such warrant approximately $3,172. The Company received notice on November 10, 2010 that such warrant was being exercised in full, and issued 1,183,712 shares of its common stock for an aggregate exercise price of approximately $15,009. Upon exercise, the Company recognized a gain of approximately $3,208 related to the transaction. For additional information on the Series I Warrants see note 18.

        The Series II Warrants became exercisable on November 5, 2008 upon the failure of the California Alternative Fuel Vehicles and Renewable Energy Act, or Proposition 10, in the California statewide election. The Series II Warrants were all exercised on a cashless basis at the exercise price of $0.01 per share, which resulted in the issuance of 1,134,759 shares of common stock to the Series II Warrant holders on November 12, 2008.

        Concurrently with the execution of the GE Credit Agreement on November 7, 2012, the Company issued to GE a warrant (the "GE Warrant") to purchase up to an aggregate of five million shares of the Company's common stock, par value $0.0001 per share ("Shares"), at a price per share of $0.01. The Shares subject to the GE Warrant are exercisable pursuant to the following schedule: (i) 500,000 Shares are immediately exercisable, (ii) an additional 1,250,000 shares will become exercisable at the time that the first Tranche A Loan is made under the GE Credit Agreement, (iii) an additional 1,250,000 shares will become exercisable at the time that the first Tranche B Loan is made under the GE Credit Agreement, (iv) an additional 1,000,000 shares will become exercisable at the time that Tranche A Loans in aggregate principal amount of at least $15,000 have been made under the GE Credit Agreement, and (v) the remaining 1,000,000 Shares will become exercisable at the time that Tranche B Loans in aggregate principal amount of at least $15,000 have been made under the GE Credit Agreement; provided, however, that if no Loans are made as contemplated by (ii) through (v) above pursuant to the GE Credit Agreement, an additional 500,000 Shares will be exercisable. The GE Warrant terminates on November 7, 2022. During the exercise period, if the Company issues or sells any shares other than exempted securities (as defined in the GE Warrant) for a price per share less than a price equal to 80% of the market price on the day of such issue or sale (the foregoing a "Dilutive Issuance"), then immediately after such Dilutive Issuance the number of shares then purchasable shall be increased on a proportionate basis by a formula set forth in the GE Warrant.

        In connection with the GE Warrant, on November 7, 2012, the Company and GE entered into a warrant agreement (the "GE Warrant Agreement") and a registration rights agreement (the "GE Registration Rights Agreement"). Pursuant to the GE Registration Rights Agreement, the Company agreed, subject to the terms and conditions of that agreement, to (i) file with the Securities and

97


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(11) Stockholders' Equity (Continued)

Exchange Commission one or more registration statements relating to the resale of Shares issuable upon exercise of the GE Warrant, and (ii) at the request of the GE Warrant holder, if a registration statement with respect to the Shares is not then effective, participate in one or more underwritten offerings of Shares issuable upon exercise of the Warrant. If the Company does not meet certain of its obligations under the GE Registration Rights Agreement with respect to the registration of Shares, it will be required to pay certain liquidated damages. As of December 31, 2012, the Company met its obligations under the GE Registration Rights Agreement.

        The Company measured the fair value of the 5,000,000 shares of the GE Warrant at $56,158 and recorded the amount in additional paid-in-capital and other long-term assets as a deferred financing cost. The fair value of the 500,000 shares that are immediately exercisable is being amortized over the estimated term of the GE Credit Agreement on the straight-line basis. The fair value of the remaining 4,500,000 shares will be allocated proportionately to the draws of the related loans as they become exercisable and amortized over the estimated term of the draws using the effective interest method. The issuance of these warrants is not included in the consolidated statements of cash flows as it is a non-cash financing activity.

Conversion of Convertible Debts into Common Stock

        In April 2012, $1,003 of principal and accrued interest under a SLG Note was converted by the holder thereof into 66,888 shares of the Company's common stock.

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 years ended December 31, 2010, 2011 and 2012:

 
   Years Ended December 31,  
 
   2010   2011   2012  

Stock-based compensation expense

   $ 11,920   $ 13,473   $ 22,087  
               

Stock-based compensation expense, net of tax

   $ 11,920   $ 13,473   $ 22,087  
               

    Stock Option Plans

        In December 2002, the Company adopted its 2002 Stock Option Plan ("2002 Plan"). The board of directors determines eligibility, vesting schedules, and exercise prices for options granted under the 2002 Plan. Options generally have a term of ten years.

        Under the 2002 Plan, eligible persons may be issued options for services rendered to the Company. Under the 2002 Plan, the purchase price per share for each option granted shall not be less than 100% of the fair market value of the Company's common stock on the date of such option grant; provided, however, that the purchase price per share of common stock issued to a 10% stockholder shall not be less than 110% of such fair market value on the date of such option grant. Options generally vest over a three-year period.

98


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(11) Stockholders' Equity (Continued)

        In December 2006, the Company adopted its 2006 Equity Incentive Plan ("2006 Plan"). The 2006 Plan was effective on May 24, 2007, the date the Company completed its initial public offering of common stock. The 2002 Plan became unavailable for new awards upon the effectiveness of the 2006 Plan. If any outstanding option under the 2002 Plan expires or is cancelled, the shares allocable to the unexercised portion of that option will be added to the share reserve under the 2006 Plan and will be available for grant under the 2006 Plan. As of December 31, 2012, the Company had 16,890,500 shares reserved for issuance under its option plans. At December 31, 2012, the Company had 38,715 shares available for grant under the 2006 Plan.

        Option activity for the year ended December 31, 2012 is as follows:

 
   Number of
Shares 		  Weighted
Average
Exercise
Price 		  Weighted
Average
Remaining
Contractual
Term
(in years) 		  Aggregate
Intrinsic
Value 		 

Outstanding, December 31, 2011

     10,683,303   $ 10.29              

Options granted

     3,194,000     13.88              

Options exercised

     (1,568,480 )   5.72              

Options forfeited

     (225,146 )   14.18              
                         

Outstanding, December 31, 2012

     12,083,677     11.75     6.54   $ 8,459  
                         

Exercisable, December 31, 2012

     7,981,345     10.65     5.31   $ 14,366  
                         

        As of December 31, 2012, there was $25,547 of total unrecognized compensation cost related to non-vested shares. 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 year ended December 31, 2012 was $11,831.

        The Company plans to issue new shares to its employees upon the employee's exercise of their options. The intrinsic value of all options exercised during 2010, 2011 and 2012 was $4,435, $1,626, and $18,822, respectively.

        The fair value of each option grant is estimated on the date of grant using the Black-Scholes option pricing model with the following assumptions used for grants during the year ended December 31, 2012:

Dividend yield

   0.00%

Expected volatility

   57.6% to 72.8%

Risk-free interest rate

   0.9% to 1.2%

Expected life in years

   6.0

        The weighted-average grant date fair value of options granted during the years ended December 31, 2010, 2011, and 2012, were $10.17, $8.98, and $7.95, respectively. The volatility amounts used during the period were estimated based on a certain peer group of the Company's historical volatility for a period commensurate with the expected life of the options granted, the Company's historical volatility, and the Company's implied volatility of its traded options. The expected lives used during the year were based on historical exercise periods and the Company's anticipated exercise

99


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(11) Stockholders' Equity (Continued)

periods for its outstanding options. The risk free rates used during the year were based on the U.S. Treasury yield curve for the expected life of the options at the time of grant. The Company recorded $11,920, $13,473, $14,199 of stock option expense during the years ended December 31, 2010, 2011 and 2012, respectively. The Company has not recorded any tax benefit related to its stock option expense.

    Restricted Stock Units

        The Company issued restricted stock units ("RSUs") to certain key employees during 2012. A holder of RSUs will receive one share of the Company's common stock for each RSU he holds if (x) between two years and four years from the date of grant 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 RSU grant date (the "Stock Price Condition") and (y) 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 RSUs will be automatically forfeited. The RSUs are subject to the terms and conditions of the Company's Amended and Restated 2006 Equity Incentive Plan and a Notice of Grant of Restricted Stock Unit and Restricted Stock Unit Agreement.

        The fair value of the RSUs was estimated using a binomial lattice model that incorporates a Monte Carlo Simulation (the "Monte Carlo Method").

        The following table summarizes the Company's RSU activity during the year ended December 31, 2012:

 
   Number of
Shares 		  Weighted Average
Fair Value at
Grant Date 		  Weighted
Average
Remaining
Contractual
Term (in years) 		 

Outstanding, December 31, 2011

     —     —        

Granted

     1,545,000   $ 11.42        
                   

Outstanding and non-vested, December 31, 2012

     1,545,000   $ 11.42     3.2  
                   

        As of December 31, 2012, there was $9,753 of total unrecognized compensation cost related to non-vested units. That cost is expected to be recognized over a weighted average period of 1.1 years.

        The fair value of each RSU was estimated on the date of grant using the Monte Carlo Method with the following assumptions:

 
   January 25,
2012 		  May 8,
2012 		 

Stock price on date of grant

   $ 15.11   $ 16.71  

Dividend yield

     0.00 %   0.00 %

Expected volatility

     56.51 %   58.49 %

Risk-free interest rate

     0.57 %   0.56 %

Expected life in years

     2.1     2.0  

100


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(11) Stockholders' Equity (Continued)

        The volatility amounts used during the period were estimated based on the Company's historical volatility for a period commensurate with the term of the RSUs granted and the Company's implied volatility of its traded options. The expected life of the RSUs was derived using the Monte Carlo Method. The risk free rates used during the year were based on the U.S. Treasury yield curve for the expected term of the RSUs at the date of grant. The Company recorded $7,888 of expense and has not recorded any tax benefit related to the expense of the RSUs during 2012.

Boone Pickens Warrant Agreement

        On December 28, 2006, the Company issued to Boone Pickens a five-year warrant to purchase 15,000,000 shares of the Company's common stock at an exercise price of $10.00 per share. These warrants were exercised in full in December 2011.

(12) Income Taxes

        The components of income (loss) before income taxes for the years ended December 31, 2010, 2011, and 2012 are as follows:

 
   2010   2011   2012  

U.S. 

   $ (6,048 ) $ (30,002 ) $ (91,608 )

Foreign

     1,839     (18,156 )   (7,960 )
               

  $ (4,209 ) $ (48,158 ) $ (99,568 )
               

        The provision (benefit) for income taxes consists of the following:

 
   2010   2011   2012  

Current:

                    

Federal

   $ (1,753 ) $ 206   $ 269  

State

     255     296     302  

Foreign

     117     396     (61 )
               

Total current

     (1,381 )   898     510  

Deferred:

                    

Federal

     (4,361 )   (8,012 )   (20,646 )

State

     (966 )   (1,724 )   (3,445 )

Foreign

     145     (4,075 )   (3,053 )

Change in valuation allowance

     5,127     12,210     27,928  
               

Total deferred

     (55 )   (1,601 )   784  
               

Total

   $ (1,436 ) $ (703 ) $ 1,294  
               

101


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

        Income tax expense (benefit) for the years ended December 31, 2010, 2011 and 2012 differs from the "expected" amount computed using the federal income tax rate of 35% as a result of the following:

 
   2010   2011   2012  

Computed expected tax expense (benefit)

   $ (1,473 ) $ (16,855 ) $ (34,849 )

State and local taxes, net of federal benefit

     174     202     121  

Nondeductible expenses

     (2,615 )   3,073     5,194  

Tax rate differential on foreign earnings

     (580 )   5,273     (717 )

Refund of alternative minimum taxes

     (1,323 )   —     —  

Tax credits

     (875 )   (834 )   —  

Other

     129     (148 )   (1,563 )

Change in valuation allowance

     5,127     8,586     33,108  
               

Total tax expense (benefit)

   $ (1,436 ) $ (703 ) $ 1,294  
               

        Deferred tax assets and liabilities result from differences between the financial statement carrying amounts and the tax bases of existing assets and liabilities. The tax effect of temporary differences that give rise to deferred tax assets and liabilities as of December 31, 2011 and 2012 are as follows:

 
   2011   2012  

Deferred tax assets:

              

Accrued expenses

   $ 1,163   $ 2,303  

Sales-type leases

     212     500  

Alternative minimum tax and general business credits

     3,470     3,297  

Derivative loss

     2,363     1,831  

Stock option expense

     11,611     15,259  

Other

     1,223     644  

Loss carryforwards

     55,212     79,819  
           

Total deferred tax assets

     75,254     103,653  

Less valuation allowance

     (53,329 )   (81,257 )
           

Net deferred tax assets

     21,925     22,396  
           

Deferred tax liabilities:

              

Depreciation and amortization—domestic

     (19,724 )   (20,291 )

Depreciation and amortization—foreign

     (928 )   (1,045 )

Partnership income

     (1,500 )   (2,071 )
           

Total deferred tax liabilities

     (22,152 )   (23,407 )
           

Net deferred tax assets (liabilities)

   $ (227 ) $ (1,011 )
           

        At December 31, 2012, the Company had federal and state net operating loss carryforwards of approximately $190,584 and $184,531, respectively. The Company's federal net operating loss carryforward will expire beginning in 2026. The Company's state net operating loss carryforwards begin expiring in 2013. At December 31, 2012, the Company also had federal and state capital loss carryforwards of approximately $14,544, which will expire in 2017. The Company also has a foreign loss carryforward of approximately $27,054 at December 31, 2012, which will expire beginning in 2017. Due

102


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

to the change of ownership provisions of Internal Revenue Code Section 382, utilization of a portion of the Company's net operating loss and tax credit carryforwards may be limited in future periods.

        In assessing the realizability of the net deferred tax assets, management considers whether it is more likely than not that some or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers projected future taxable income and tax planning strategies in making this assessment. As of December 31, 2011 and 2012, the Company provided a valuation allowance of $53,329, and $81,257, respectively, to reduce the net deferred tax assets due to uncertainty surrounding the realizability of these assets. The net change in the valuation allowance for the years ended December 31, 2010, 2011, and 2012 was $5,127, $12,210, and $27,928, respectively, after adjustments between current and deferred taxes.

        As of December 31, 2012, the Company has not provided deferred U.S. income taxes or foreign withholding taxes on temporary differences of approximately $2,400 resulting from earnings of certain non-U.S. subsidiaries which are permanently reinvested outside the U.S. Unrecognized deferred taxes on remittance of these funds are not expected to be material.

        On January 1, 2007, the Company adopted certain accounting guidance that clarifies the accounting for uncertain tax positions. This guidance requires that the Company recognizes the impact of a tax position in its financial statements if the position is more likely than not of being sustained upon examination, based on the technical merits of the position. The impact of the adoption of this guidance was immaterial to the Company's consolidated financial statements. The total amount of unrecognized tax benefits as of December 31, 2010, 2011, and 2012 were $50, $305, and $515, respectively, which if recognized, would primarily affect the effective tax rate in future periods.

        The following is a tabular reconciliation of the total amounts of unrecognized tax benefits for the years ended December 2011 and 2012:

Unrecognized tax benefit—December 31, 2010

   $ 50  

Gross increases—tax positions in prior years

     255  

Gross (decreases)—tax positions in prior years

     —  
       

Unrecognized tax benefit—December 31, 2011

     305  

Gross increases—tax positions in prior years

     260  

Gross (decreases)—tax positions in prior years

     (50 )
       

Unrecognized tax benefit—December 31, 2012

   $ 515  
       

        FASB authoritative guidance requires the Company to accrue interest and penalties where there is an underpayment of taxes based on the Company's best estimate of the amount ultimately to be paid. The Company's policy is to recognize interest accrued related to unrecognized tax benefits and penalties as income tax expense. During each of the years ended December 31, 2010, 2011 and 2012, the Company accrued interest of $6, $6, and $21, respectively. No penalties have been accrued by the Company.

        The Company is subject to taxation in the United States and various states and foreign jurisdictions. The Company's tax years for 2008 through 2011 are subject to examination by various tax authorities. The Company is no longer subject to U.S. examination for years before 2009, and state examinations for years before 2008.

103


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

        A number of years may elapse before an uncertain tax position is finally resolved. It is often difficult to predict the final outcome or the timing of resolution of any particular uncertain tax position, but the Company believes that its reserves for income taxes reflect the most probable outcomes. The Company adjusts the reserve, as well as the related interest, in light of changing facts and circumstances. Settlement of any particular position would usually require the use of cash and result in the reduction of the related reserve, or there could be a change in the amount of the Company's net operating loss. The resolution of a matter would be recognized as an adjustment to the provision for income taxes and the effective tax rate in the period of resolution. The Company does not expect that any of its uncertain tax positions will reverse within the next twelve months.

(13) Commitments and Contingencies

Environmental Matters

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

Litigation, Claims and Contingencies

        The Company may become party to various legal actions that arise in the ordinary course of its business. 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 at this time to determine the ultimate liabilities that the Company may incur resulting from any lawsuits, claims and proceedings, audits, commitments, contingencies and related matters or the timing of these liabilities, if any. If these matters were to be ultimately 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 or results of operations. However, the Company believes that the ultimate resolution of such actions will not have a material adverse affect on the Company's consolidated financial position, results of operations, or liquidity.

        On July 15, 2010, the Internal Revenue Service ("IRS") sent the Company a letter disallowing approximately $5,073 related to certain claims it made from October 1, 2006 to June 30, 2008 under the Volumetric Excise Tax Credit program. In December 2012, the Company reached an agreement with the IRS to settle the dispute for $2,057.

Operating Lease Commitments

        The Company leases facilities, including the land for its LNG production plant in Boron, California, and certain equipment under noncancelable operating leases expiring at various dates

104


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(13) Commitments and Contingencies (Continued)

through 2038. The following schedule represents the future minimum lease obligations for all noncancelable operating leases as of December 31, 2012:

Fiscal year:

        

2013

   $ 5,617  

2014

     5,445  

2015

     5,183  

2016

     4,996  

2017

     4,702  

Thereafter

     11,956  
       

Total future minimum lease payments

   $ 37,899  
       

        Rent expense, including variable rent, totaled $6,190, $6,517, and $7,737 for the years ended December 31, 2010, 2011 and 2012, respectively.

Take-or-Pay LNG Supply Contracts

        At December 31, 2012, the Company is party to an LNG supply contract at market prices that contains minimum take or pay provisions over the term of the contract. The contract contains fixed amounts the Company must pay for any shortfall below its minimum volume requirements and also contains a variable charge that is based on the price of natural gas for the month when a shortfall occurs. The contract, which replaced a similar contract that expired in June 2011, expires in June 2014. For the years ended December 31, 2010, 2011 and 2012, the Company paid approximately $4,281, $5,034, and $3,821, respectively, under this contract. At December 31, 2012, the fixed commitments under this contract totaled approximately $2,095, $1,049 for the years ending December 31, 2013 and 2014, respectively.

        Additionally, in October 2007, the Company entered into an LNG sales agreement with Desert Gas Services (formerly known as Spectrum Energy Services, LLC) ("DGS"), to purchase, on a take-or-pay basis over a term of ten years, 45,000 gallons per day of LNG from a plant constructed by DGS in Ehrenberg, Arizona, which is near the California border. This obligation began in March 2010, and for the years ended December 31, 2010, 2011 and 2012, the Company paid approximately $4,041, $7,599, and $8,153, respectively, under the take-or-pay supply contract. The contract expires in October 2017. At December 31, 2012, the fixed commitments under this contract totaled approximately $3,058 for each of the years ending December 31, 2013 through December 31, 2016, and $2,549 for the year ended December 31, 2017.

(14) Geographic Information

        Several of the Company's functions, including marketing, engineering, and finance are performed at the corporate level. As a result, significant interdependence and overlap exists among the Company's geographic areas. Accordingly, revenue, operating income (loss), and long-lived assets shown for each geographic area may not be the amounts which would have been reported if the geographic areas were independent of one another. Revenue by geographic area is based on where services are rendered and

105


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(14) Geographic Information (Continued)

finished goods are sold. Operation income (loss) is based on the location of the entity selling the finished goods or providing the services.

 
   2010   2011   2012  

Revenue:

                    

United States

   $ 194,512   $ 248,419   $ 286,125  

Canada

     6,158     4,800     8,364  

Other

     11,164     39,498     39,519  
               

Total revenue

   $ 211,834   $ 292,717   $ 334,008  
               

Operating income (loss):

                    

United States

   $ (7,251 ) $ (33,761 ) $ (69,030 )

Canada

     1,386     (5,844 )   (188 )

Other

     343     1,037     (1,304 )
               

Total operating income (loss)

   $ (5,522 ) $ (38,568 ) $ (70,522 )
               

Long-lived assets:

                    

United States

   $ 262,545   $ 325,386   $ 480,067  

Canada

     133,078     121,103     122,291  

Other

     2,287     3,277     3,547  
               

Total long-lived assets

   $ 397,910   $ 449,766   $ 605,905  
               

        The Company's goodwill and intangible assets at December 31, 2010, 2011 and 2012 relate to its United States operations, its BAF operations, IMW operations, and Northstar operations.

(15) 401(k) Plan

        The Company has established a savings plan ("Savings Plan") which is qualified under Section 401(k) of the Internal Revenue Code. Eligible employees may elect to make contributions to the Savings Plan through salary deferrals of up to 90% of their base pay, subject to Internal Revenue Code limitations. The Company may make discretionary contributions to the Savings Plan that are subject to limitations. For the years ended December 31, 2010, 2011 and 2012, the Company contributed approximately $551, $798, and $1,289 of matching contributions to the Savings Plan, respectively.

(16) Supplier Concentrations

        During 2010, 2011, and 2012, the Company incurred approximately 9%, 9%, and 8%, respectively, of its natural gas expense related to its LNG sales from Williams Gas Processing Company pursuant to a floating rate purchase contract that includes minimum purchase commitments. During 2010, 2011, and 2012, the Company incurred approximately 31%, 30% and 31%, respectively, of its natural gas expense related to its LNG sales from Shell Energy, which supplies the Company's LNG plant in California and DGS's plant in Arizona where the Company has a take or pay obligation. During 2010, 2011 and 2012, the Company incurred approximately 17%, 16%, and 16%, respectively, of its natural gas costs related to its CNG operations from the SoCal Gas Company and San Diego Gas and Electric.

106


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(16) Supplier Concentrations (Continued)

Any inability to obtain natural gas in the amounts needed on a timely basis or at commercially reasonable prices could result in interruption of gas deliveries or increases in gas costs, which could have a material adverse effect on the Company's business, financial condition, and results of operations until alternative sources could be developed at a reasonable cost.

(17) Capitalized Lease Obligation and Receivables

        The Company leases equipment under capital leases with a weighted-average interest rate of 7.2%. At December 31, 2012, future payments under these capital leases are as follows:

2013

   $ 2,069  

2014

     1,195  

2015

     400  

2016

     35  

2017

     36  

Thereafter

     56  
       

Total minimum lease payments

     3,791  

Less amount representing interest

     (223 )
       

Present value of future minimum lease payments

     3,568  

Less current portion

     (1,892 )
       

Capital lease obligations, less current portion

   $ 1,676  
       

        The value of the equipment under capital lease as of December 31, 2011 and 2012 was $6,802 and $6,802, with related accumulated amortization of $1,378 and $1,834, respectively.

        The Company also leases certain fueling station equipment to certain customers under sales-type leases at a weighted average effective interest rate of 4.8%. The leases are payable in varying monthly installments through February 2017.

        At December 31, 2012, future receipts under these leases are as follows:

2013

   $ 377  

2014

     377  

2015

     377  

2016

     377  

2017

     256  
       

Total

     1,767  

Less amount representing interest

     (193 )
       

  $ 1,574  
       

(18) 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

107


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(18) Fair Value Measurements (Continued)

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 twelve months ended December 31, 2012, the Company's financial instruments consisted of available-for-sale securities, natural gas futures contracts, debt instruments, a contingent consideration obligation, and its Series I warrants. For securities available-for-sale, the fair value is determined by the most recent trading prices available for each security or for comparable securities, and thus represent Level 2 fair value measurements. The Company uses quoted forward price curves, discounted to reflect the time value of money, to value its natural gas futures contracts which is considered to be a Level 2 fair value measurement. The Company uses projected financial results for the respective entities, discounted to reflect the time value of money, to value its contingent consideration obligations which are considered to be Level 3 fair value measurements. The fair market value of the Company's debt instruments approximated their carrying values at December 31, 2012. The Company uses the Black-Scholes model to value the Series I warrants. The Company believes the best method to approximate the 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 3.33 years as of December 31, 2012. This method has been utilized consistently in the periods presented. Given 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 determination in the table below.

108


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(18) Fair Value Measurements (Continued)

        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, 2011 and December 31, 2012, respectively:

Description
  Balance at
December 31, 2011 		  Level 1   Level 2   Level 3  

Assets:

                          

Available-for-sale securities(1):

                          

Certificate of deposits

   $ 10,000   $ —   $ 10,000   $ —  

Municipal bonds and notes

     19,589     —     19,589     —  

Zero coupon bonds

     712     —     712     —  

Corporate bonds

     3,028     —     3,028     —  

Liabilities:

                          

Natural gas futures contracts(2)

     2,335     —     2,335     —  

Contingent consideration obligation(3)

     5,978     —     —     5,978  

Series I warrants(4)

     11,493     —     —     11,493  

 

Description
  Balance at
December 31, 2012 		  Level 1   Level 2   Level 3  

Assets:

                          

Available-for-sale securities(1):

                          

Certificate of deposits

   $ 10,021   $ —   $ 10,021   $ —  

Municipal bonds and notes

     23,650     —     23,650     —  

Corporate bonds

     4,504     —     4,504     —  

Liabilities:

                          

Natural gas futures contracts(2)

     107     —     107     —  

Contingent consideration obligation(3)

     1,516     —     —     1,516  

Series I warrants(4)

     8,102     —     —     8,102  
(1)
Included in short-term investments in the consolidated balance sheets. See note 4 for further information.

(2)
See note 10 for further information.

(3)
The current portion is included in accrued liabilities, and the long-term portion is included in other long-term liabilities in the consolidated balance sheets.

(4)
Included in other long-term liabilities in the consolidated balance sheets.

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(18) Fair Value Measurements (Continued)

        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: Contingent Consideration
  2011   2012  

Beginning Balance

   $ 11,200   $ 5,978  

Business combinations

     —     —  

Total (gain) loss included in earnings

     (2,828 )   (4,112 )

Payments

     (2,394 )   (350 )

Transfers In/Out

     —     —  
           

Ending Balance

   $ 5,978   $ 1,516  
           

 

Liabilities: Series I Warrants
  2011   2012  

Beginning Balance

   $ 14,148   $ 11,493  

Total (gain) loss included in earnings

     (2,655 )   (3,391 )

Issuance of warrants

     —     —  

Exercise of warrants

     —     —  

Transfers In/Out

     —     —  
           

Ending Balance

   $ 11,493   $ 8,102  
           

        During the fourth quarter of 2010, the Company recorded an impairment of $1,531 of an acquired operating and maintenance contract lost in a competitive bid to a competitor. In addition, during the fourth quarter of 2010, the Company's subsidiary, DCE, expensed approximately $717 of costs related to equipment that was replaced as part of its expansion of the McCommas Bluff landfill in Dallas, Texas. During the fourth quarter of 2012, the Company recorded an impairment of $14,544 related to its investment in VPG due to a permanent decline in its value. There were no long-lived asset impairments in 2011.

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.

Contingent Consideration

        Pursuant to the terms presented in the Asset Purchase Agreement, the IMW shareholder will earn additional consideration if IMW achieves certain minimum gross profit targets in fiscal years 2011 through 2014. Therefore, the Company estimated the fair value of the contingent consideration using a

110


CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(18) Fair Value Measurements (Continued)

discounted cash flow model that considers the payout structure based on the following inputs as of December 31, 2012:

Unobservable Input
  Range or Weighted Average

Gross profit projection

   $14,162–$32,641

Probability of reaching target gross profit

   0.0%–75.0%

Volatility of gross profit (peer group)

   14.6%–55.2% (simple average 31.4%)

Risk adjusted discount rate

   35.9%

        Significant changes in any of those inputs in isolation would result in a significant change in the fair value measurement. Generally, a positive change in the assumptions used for the probability of achieving a higher gross profit target threshold would result in a directionally similar change in the estimated fair value of the contingent consideration, and thus an increase in the associated liability. Conversely, an increase in the assumed discount rate would have a directionally opposite impact on the estimated fair value measurement of the contingent consideration, and would result in a decrease in the associated liability.

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 December 31, 2012:

Unobservable Input
  Range or Weighted Average  

Current market price of the Company's common stock

     $12.45  

Exercise price of the warrant

     $12.68  

Dividend yield

     0.00%  

Remaining term of the warrant

     3.33  

Implied volatility of the Company's common stock

     45.2%–47.2%  

Assumed discount rate

     Simple average 0.4%  

        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 warrant 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 plans to, declare dividends on its common stock, and thus, there is no directionally similar change in the estimated fair value of the warrants due to the dividend assumption.

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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(In thousands, except share and per share data)

(19) Subsequent Events

        On January 2, 2013, the American Taxpayer Relief Act was signed into law which extended VETC through December 31, 2013 and made it retroactive to January 1, 2012. Such credits for 2012 are estimated to be approximately $20,800, which will be recognized during the first quarter of 2013.

        The Company has entered into an agreement to sell its ownership interest in Peru JV for approximately $6,100 after receiving a dividend distribution of approximately $1,027. The Company expects to close the sale by March 31, 2013.

        In January and February 2013, $4,030 of principal and accrued interest under an SLG Note was converted by the holder into 268,664 shares of the Company's common stock.

Item 9.    Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.

        None.

Item 9A.    Controls and Procedures.

Evaluation of disclosure controls and procedures.

        Our management, under the supervision and with the participation of our Chief Executive Officer and Chief Financial Officer (our principal executive and principal financial officers, respectively), evaluated the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 under the Securities Exchange Act of 1934, as amended (the "Exchange Act"). In designing and evaluating the disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives. In addition, the design of disclosure controls and procedures must reflect the fact that there are resource constraints and that management is required to apply its judgment in evaluating the benefits of possible controls and procedures relative to their costs.

        Based on management's evaluation, our Chief Executive Officer and Chief Financial Officer concluded that, as of December 31, 2012, our disclosure controls and procedures are designed at a reasonable assurance level and are effective to provide reasonable assurance that information we are required to disclose in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms, 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.

Changes in internal control over financial reporting.

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

Management's Report on Internal Control Over Financial Reporting

        Our management is responsible for establishing and maintaining adequate internal control over our financial reporting (as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934, as

112

amended). Our management assessed the effectiveness of our internal controls over financial reporting as of December 31, 2012. In making its assessment of the effectiveness of our internal controls over financial reporting, our management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission ("COSO") in Internal Control—Integrated Framework. Based on these criteria, our management has concluded that, as of December 31, 2012, our internal control over financial reporting is effective. Our independent registered public accounting firm, KPMG LLP, has issued an audit report on our assessment of our internal control over financial reporting, which is included in Part II, Item 8 of this Form 10-K.


PART III

Item 10.    Directors, Executive Officers and Corporate Governance.

        The information required by this item is incorporated by reference to the proxy statement for our 2013 Annual Meeting of Stockholders to be filed with the SEC within 120 days after the end of the fiscal year ended December 31, 2012.

Item 11.    Executive Compensation.

        The information required by this item is incorporated by reference to the proxy statement for our 2013 Annual Meeting of Stockholders to be filed with the SEC within 120 days after the end of the fiscal year ended December 31, 2012.

Item 12.    Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.

        The information required by this item is incorporated by reference to the proxy statement for our 2013 Annual Meeting of Stockholders to be filed with the SEC within 120 days after the end of the fiscal year ended December 31, 2012.

Item 13.    Certain Relationships and Related Transactions and Director Independence.

        The information required by this item is incorporated by reference to the proxy statement for our 2013 Annual Meeting of Stockholders to be filed with the SEC within 120 days after the end of the fiscal year ended December 31, 2012.

Item 14.    Principal Accounting Fees and Services.

        The information required by this item is incorporated by reference to the proxy statement for our 2013 Annual Meeting of Stockholders to be filed with the SEC within 120 days after the end of the fiscal year ended December 31, 2012.

113


 PART IV

Item 15.    Exhibits and Financial Statement Schedules.

        (a)(1) Consolidated Financial Statements.

        The following documents are filed in Part II, Item 8 of this annual report on Form 10-K:

Report of Independent Registered Public Accounting Firm

    

Consolidated Balance Sheets as of December 31, 2011 and 2012

    

Consolidated Statements of Operations for the Years Ended December 31, 2010, 2011 and 2012

    

Consolidated Statements of Comprehensive Income (loss) for Years Ended December 31, 2010, 2011 and 2012

    

Consolidated Statements of Stockholders' Equity for the Years Ended December 31, 2010, 2011 and 2012

    

Consolidated Statements of Cash Flows for the Years Ended December 31, 2010, 2011 and 2012

    

Notes to Consolidated Financial Statements

    

        (a)(2) Financial Statement Schedules.

        The following financial statement schedule is filed as a part of this annual report on Form 10-K:

    Schedule II: Valuation and Qualifying Accounts

        All other schedules have been omitted as they are not required, not applicable, or the required information is otherwise included.

 
   Allowances for Doubtful Trade Receivables   Allowance for Doubtful Notes Receivables  

Balance at December 31, 2009

   $ 898   $ 216  

Charges (benefit) to operations

     264     —  

Deductions

     (460 )   (123 )
           

Balance at December 31, 2010

     702     93  

Charges (benefit) to operations

     344     —  

Deductions

     (334 )   (73 )
           

Balance at December 31, 2011

     712     20  

Charges (benefit) to operations

     434     924  

Deductions

     (242 )   (35 )
           

Balance at December 31, 2012

   $ 904   $ 909  
           

114

        (a)(3) Exhibits.

 
    
   Incorporated herein by reference to the following filings:
Exhibit Number    
  Description   Form   Filed on
  2.3   Asset Purchase Agreement, dated July 1, 2010, among Clean Energy, a California corporation, 0884808 B.C. Ltd., a British Columbia corporation, and 0884810 B.C. Ltd., a British Columbia corporation, on the one hand, and I.M.W. Industries Ltd., a British Columbia corporation, 652322 B.C. Ltd., a British Columbia corporation, Miller Family Trust and Bradley N. Miller, on the other hand.   Filed as Exhibit 2.5 to the Current Report on Form 8-K.   July 6, 2010
  2.4   Amendment to Asset Purchase Agreement, dated as of September 7, 2010, by and among Clean Energy, a California corporation, 0884808 B.C. Ltd., a British Columbia corporation and a wholly-owned subsidiary of Clean Energy—CA, and Clean Energy Compression Corp, a British Columbia corporation formerly known as 0884810 B.C. Ltd and a wholly-owned subsidiary of Canadian AcqCo, on the one hand, and I.M.W. Industries Ltd., a British Columbia Corporation, B&M Miller Equity Holdings Inc., a successor by amalgamation to 652322 B.C. Ltd., a British Columbia corporation, Bradley N. Miller, Marion G. Miller and Miller Family Trust, on the other hand.   Filed as Exhibit 2.6 to the Current Report on Form 8-K.   September 7, 2010
  3.1   Restated Certificate of Incorporation.   Filed as Exhibit 3.1 to the Registration Statement on Form S-1, as amended.   March 27, 2007
  3.1.1   Restated Certificate of Incorporation, as amended, by the Certificate of Amendment to the Restated Certificate of Incorporation of Registrant dated May 28, 2010.   Filed as Exhibit 3.1.1 to the Quarterly Report on Form 10-Q for the quarter ended June 30, 2010.   August 9, 2010
  3.2   Amended and Restated Bylaws.   Filed as Exhibit 3.2 to the Current Report on Form 8-K.   February 23, 2011
  4.1   Specimen Common Stock Certificate.   Filed as Exhibit 4.1 to the Registration Statement on Form S-1, as amended.   March 27, 2007

115

 
    
   Incorporated herein by reference to the following filings:
Exhibit Number    
  Description   Form   Filed on
  4.5   Form of Warrant to Purchase Common Stock.   Filed as Exhibit 4.5 to the Current Report on Form 8-K.   October 29, 2008
  4.6   Convertible Promissory Note issued by the Registrant to Chesapeake NG Ventures Corporation.   Filed as Exhibit 4.6 to the Current Report on Form 8-K.   July 11, 2011
  4.7   Form of Convertible Note.   Filed as Exhibit 4.7 to the Current Report on Form 8-K.   August 30, 2011
  4.8   Warrant to Purchase Common Stock issued by the Registrant to GE Energy Financial Services, Inc. dated November 7, 2012   Filed as Exhibit 4.8 to the Current Report on Form 8-K.   November 13, 2012
  10.1+   2002 Stock Option Plan, Amendment and Form of Stock Option Agreement.   Filed as Exhibit 10.1 to the Registration Statement on Form S-1, as amended.   September 6, 2006
  10.3   Lease Agreement dated August 12, 1999 between the Registrant and Bixby Office Park Associates, LLC.   Filed as Exhibit 10.3 to the Registration Statement on Form S-1, as amended.   March 27, 2007
  10.4   Form of Indemnification Agreement.   Filed as Exhibit 10.4 to the Registration Statement on Form S-1, as amended.   March 27, 2007
  10.5+   Amended and Restated 2002 Stock Option Plan dated August 10, 2007.   Filed as Exhibit 99.1 to the Registration Statement on Form S-8.   August 14, 2007
  10.6+   Stock Option Agreement dated May 18, 2006 between the Registrant and G. Michael Boswell.   Filed as Exhibit 99.3 to the Registration Statement on Form S-8.   August 14, 2007
  10.7+   2006 Equity Incentive Plan—Form of Notice of Stock Option Grant and Stock Option Agreement.   Filed as Exhibit 99.5 to the Registration Statement on Form S-8.   August 14, 2007
  10.12†   Ground Lease dated November 3, 2006 among the Registrant, Clean Energy Construction and U.S. Borax, Inc.   Filed as Exhibit 10.25 to the Registration Statement on Form S-1, as amended.   May 24, 2007
  10.13   Warrant to Purchase Common Shares dated December 28, 2006 issued by the Registrant to Boone Pickens.   Filed as Exhibit 10.26 to the Registration Statement on Form S-1, as amended.   March 27, 2007
  10.16+   2006 Equity Incentive Plan—Form of Stock Award Agreement.   Filed as Exhibit 10.2 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2008.   May 15, 2008

116

 
    
   Incorporated herein by reference to the following filings:
Exhibit Number    
  Description   Form   Filed on
  10.20   Sixth Amendment to Lease Agreement dated August 1, 2008 among the Registrant, Clean Energy and Bixby Office Park, LLC.   Filed as Exhibit 10.3 to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2008.   November 14, 2008
  10.21+   Amendment No. 1 to Amended and Restated 2002 Stock Option Plan.   Filed as Exhibit 10.36 to the Annual Filing on Form 10-K for the fiscal year ended 2007.   March 19, 2008
  10.22   First Amendment to Base Contract for Sale and Purchase of Natural Gas dated November 1, 2008, between the Registrant and Shell Energy North America (US), L.P.   Filed as Exhibit 10.4 to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2008.   November 14, 2008
  10.23   Guaranty dated November 7, 2008, by the Registrant in favor of Shell Energy North America (US), L.P.   Filed as Exhibit 10.5 to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2008.   November 14, 2008
  10.24+   Amended and Restated Employment Agreement dated December 31, 2008, between the Registrant and Andrew J. Littlefair.   Filed as Exhibit 99.1 to the Current Report on Form 8-K.   December 31, 2008
  10.25+   Amended and Restated Employment Agreement dated December 31, 2008, between the Registrant and Richard R. Wheeler.   Filed as Exhibit 99.2 to the Current Report on Form 8-K.   December 31, 2008
  10.26+   Amended and Restated Employment Agreement dated December 31, 2008, between the Registrant and Mitchell W. Pratt.   Filed as Exhibit 99.3 to the Current Report on Form 8-K.   December 31, 2008
  10.27+   Amended and Restated Employment Agreement dated December 31, 2008, between the Registrant and James N. Harger.   Filed as Exhibit 99.4 to the Current Report on Form 8-K.   December 31, 2008
  10.32†   Base Contract for Sale and Purchase of Natural Gas between Shell Energy North America (US), LP and Dallas Clean Energy, LLC.   Filed as Exhibit 10.50 to the Quarterly Report on Form 10-Q for the quarter ended June 30, 2009.   August 10, 2009
  10.37+   Employment Agreement dated February 17, 2010, between the Registrant and Barclay Corbus.   Filed as Exhibit 99.1 to the Current Report on Form 8-K.   February 18, 2010
  10.39   Form of Future Payment Note, issued by Clean Energy Compression Corp. to I.M.W. Industries Ltd.   Filed as Exhibit 10.58 to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2010.   November 8, 2010

117

 
    
   Incorporated herein by reference to the following filings:
Exhibit Number    
  Description   Form   Filed on
  10.40   Form of Security Agreement between Clean Energy Compression Corp. and I.M.W. Industries Ltd.   Filed as Exhibit 10.59 to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2010.   November 8, 2010
  10.41   Form of Commitment to Provide Funds, between Clean Energy Compression Corp., 0884808 B.C. Ltd., and HSBC Bank Canada.   Filed as Exhibit 10.60 to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2010.   November 8, 2010
  10.42   Form of Commitment to Provide Funds, between Clean Energy Compression Corp., 0884808 B.C. Ltd., and HSBC Bank Canada   Filed as Exhibit 10.61 to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2010.   November 8, 2010
  10.47   Seventh Amendment to Lease Agreement, dated September 23, 2010, between Clean Energy and BixbyBIT—Bixby Office Park, LLC.   Filed as Exhibit 10.66 to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2010.   November 8, 2010
  10.50   Loan Agreement dated January 1, 2011, between Mission Economic Development Corporation and Dallas Clean Energy McCommas Bluff, LLC.   Filed as Exhibit 10.50 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2011.   May 9, 2011
  10.51   Depository and Control Agreement dated January 1, 2011, among Dallas Clean Energy McCommas Bluff, LLC, The Bank of New York Mellon Trust Company, N.A. as Depository Bank and The Bank of New York Mellon Trust Company, N.A.   Filed as Exhibit 10.51 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2011.   May 9, 2011
  10.52   Trust Indenture dated January 1, 2011, between Mission Economic Development Corporation and The Bank of New York Mellon Trust Company, N.A.   Filed as Exhibit 10.52 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2011.   May 9, 2011
  10.53   Bond Purchase Contract dated March 24, 2011, among Mission Economic Development Corporation, First Southwest Company, Westhoff, Cone & Holmstedt and Dallas Clean Energy McCommas Bluff, LLC.   Filed as Exhibit 10.53 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2011.   May 9, 2011
  10.55   Security Agreement dated March 31, 2011, between Dallas Clean Energy McCommas Bluff, LLC, and The Bank of New York Mellon Trust Company, N.A.   Filed as Exhibit 10.55 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2011.   May 9, 2011

118

 
    
   Incorporated herein by reference to the following filings:
Exhibit Number    
  Description   Form   Filed on
  10.56   Leasehold Deed of Trust, Security Agreement and Assignment of Rents and Leases dated March 31, 2011 by Dallas Clean Energy McCommas Bluff, LLC to Peter S. Graf.   Filed as Exhibit 10.56 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2011.   May 9, 2011
  10.58   Loan Agreement dated July 11, 2011 between Registrant and Chesapeake NG Ventures Corporation.   Filed as Exhibit 10.58 to the Current Report on Form 8-K.   July 11, 2011
  10.59   Registration Rights Agreement dated July 11, 2011 between Registrant and Chesapeake NG Ventures Corporation.   Filed as Exhibit 10.59 to the Current Report on Form 8-K.   July 11, 2011
  10.60   Form of Convertible Note Purchase Agreement.   Filed as Exhibit 10.60 to the Current Report on Form 8-K.   August 30, 2011
  10.61   Form of Registration Rights Agreement   Filed as Exhibit 10.61 to the Current Report on Form 8-K.   August 30, 2011
  10.62   Eighth Amendment to Lease Agreement, dated January 6, 2012, between Clean Energy and Western National Life Insurance Company (as successor-in-interest to BixbyBIT)—Bixby Office Park, LLC.   Filed as Exhibit 10.62 to the Annual Filing on Form 10-K for the fiscal year ended 2011.   March 12, 2012
  10.63+   Amended and Restated 2006 Equity Incentive Plan   Filed as Exhibit 10.63 to the Annual Filing on Form 10-K for the fiscal year ended 2011.   March 12, 2012
  10.64+   Amended and Restated 2006 Equity Incentive Plan—Form of Notice of Stock Unit Award and Stock Unit Agreement   Filed as Exhibit 10.64 to the Annual Filing on Form 10-K for the fiscal year ended 2011.   March 12, 2012
  10.65+   First Amendment to Amended and Restated Employment Agreement dated February 17, 2012, between the Registrant and Andrew J. Littlefair.   Filed as Exhibit 10.65 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2012.   May 7, 2012
  10.66+   First Amendment to Amended and Restated Employment Agreement dated February 17, 2012, between the Registrant and Richard R. Wheeler.   Filed as Exhibit 10.66 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2012.   May 7, 2012
  10.67+   First Amendment to Amended and Restated Employment Agreement dated February 17, 2012, between the Registrant and Mitchell W. Pratt.   Filed as Exhibit 10.67 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2012.   May 7, 2012

119

 
    
   Incorporated herein by reference to the following filings:
Exhibit Number    
  Description   Form   Filed on
  10.68+   First Amendment to Amended and Restated Employment Agreement dated February 17, 2012, between the Registrant and James N. Harger.   Filed as Exhibit 10.68 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2012.   May 7, 2012
  10.69+   First Amendment to Employment Agreement dated February 17, 2012, between the Registrant and Barclay F. Corbus.   Filed as Exhibit 10.69 to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2012.   May 7, 2012
  10.70   Credit Agreement among Clean Energy Tranche A LNG Plant, LLC and Clean Energy Tranche B LNG Plant, LLC, as Borrowers, the Various Financial Institutions from Time to Time Party thereto, as Lenders, and General Electric Capital Corporation, as Administrative Agent and Collateral Agent, dated as of November 7, 2012.   Filed as Exhibit 10.70 to the Current Report on Form 8-K.   November 13, 2012
  10.71†*   Guaranty by Clean Energy Fuels Corp. in favor of General Electric Capital Corporation, dated as of November 7, 2012.        
  10.72   Equity Contribution Agreement by and among Clean Energy Tranche A LNG Plant, LLC and Clean Energy Tranche B LNG Plant, LLC, as Borrowers, Clean Energy Fuels Corp., as Equity Investor, and General Electric Capital Corporation, as Administrative Agent and Collateral Agent, dated as of November 7, 2012.   Filed as Exhibit 10.72 to the Current Report on Form 8-K.   November 13, 2012
  10.73   Warrant Agreement between the Registrant and GE Energy Financial Services, Inc., dated as of November 7, 2012.   Filed as Exhibit 10.73 to the Current Report on Form 8-K.   November 13, 2012
  10.74   Registration Rights Agreement between the Registrant and GE Energy Financial Services, Inc., dated as of November 7, 2012.   Filed as Exhibit 10.74 to the Current Report on Form 8-K.   November 13, 2012
  10.75+*   Second Amendment to Amended and Restated Employment Agreement dated December 12, 2012, between the Registrant and Andrew J. Littlefair.        
  10.76+*   Second Amendment to Amended and Restated Employment Agreement dated December 12, 2012, between the Registrant and Richard R. Wheeler.        

120

 
    
   Incorporated herein by reference to the following filings:
Exhibit Number    
  Description   Form   Filed on
  10.77+*   Second Amendment to Amended and Restated Employment Agreement dated December 12, 2012, between the Registrant and Mitchell W. Pratt.        
  10.78+*   Second Amendment to Amended and Restated Employment Agreement dated December 12, 2012, between the Registrant and James N. Harger.        
  10.79+*   Second Amendment to Employment Agreement dated December 12, 2012, between the Registrant and Barclay F. Corbus.        
  18.1   Letter from KMPG LLP re Change in Accounting Principles.   Filed as Exhibit 18.1 to Annual Report on Form 10-K   March 12, 2012
  21.1*   Subsidiaries.        
  23.1*   Consent of Independent Registered Public Accounting Firm KPMG LLP.        
  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 Richard R. Wheeler, 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 Richard R. Wheeler, Chief Financial Officer.        
  99.1   Natural Gas Hedge Policy dated May 29, 2008.   Filed as Exhibit 99.1 to the Current Report on Form 8-K.   June 20, 2008

121

 
    
   Incorporated herein by reference to the following filings:
Exhibit Number    
  Description   Form   Filed on
  101***   The following materials from the Company's Annual Report on Form 10-K for the year ended December 31, 2012, formatted in XBRL (eXtensible Business Reporting Language):        
      (i) Consolidated Balance Sheet at December 31, 2012;        
      (ii) Consolidated Statement of Operations for the year ended December 31, 2012;        
      (iii) Consolidated Statements of Comprehensive Income (Loss) for the Years Ended December 31, 2010, 2011, and 2012        
      (iv) Consolidated Statement of Cash Flows for the year ended December 31, 2012; and        
      (v) Notes to Consolidated Financial Statements tagged in block of text.        
†
Portions of this exhibit have been omitted pursuant to a request for confidential treatment and the non-public information has been filed separately with the SEC.

*
Filed herewith.

**
Furnished herewith.

***
Pursuant to Rule 406T of Regulation S-T, the Interactive Data Files on Exhibit 101 hereto are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections.

+ Management contract or compensatory plan or arrangement.

122


 SIGNATURES

        Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

    CLEAN ENERGY FUELS CORP.

 
 
By:
 
/s/ ANDREW J. LITTLEFAIR
 Andrew J. Littlefair
 President and Chief Executive Officer

Date: February 28, 2013

        Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

Signature
 
Title
 
Date

 
 
 
 
 
/s/ ANDREW J. LITTLEFAIR
 Andrew J. Littlefair		   President, Chief Executive Officer (Principal Executive Officer) and a Director   February 28, 2013

/s/ RICHARD R. WHEELER
 Richard R. Wheeler
 
Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer)
 
February 28, 2013

/s/ WARREN I. MITCHELL
 Warren I. Mitchell
 
Chairman of the Board and Director
 
February 28, 2013

/s/ VINCENT C. TAORMINA
 Vincent C. Taormina
 
Director
 
February 28, 2013

/s/ JOHN S. HERRINGTON
 John S. Herrington
 
Director
 
February 28, 2013

/s/ JAMES C. MILLER III
 James C. Miller III
 
Director
 
February 28, 2013

/s/ BOONE PICKENS
 Boone Pickens
 
Director
 
February 28, 2013

123

Signature
 
Title
 
Date

 
 
 
 
 
/s/ JAMES E. O'CONNOR
 James E. O'Connor		   Director   February 28, 2013

/s/ KENNETH M. SOCHA
 Kenneth M. Socha
 
Director
 
February 28, 2013

124



QuickLinks

CAUTIONARY NOTE REGARDING FORWARD LOOKING STATEMENTS
PART I
Representative Annual per Vehicle Fuel Cost Savings by Fleet Market for California Based on Average Fuel Prices During 2012
PART II
INDEX TO FINANCIAL STATEMENTS
Report of Independent Registered Public Accounting Firm
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS (In thousands, except share data)
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF OPERATIONS (In thousands, except share and per share data)
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (In thousands)
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (In thousands, except share data)
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CASH FLOWS (In thousands)
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (In thousands, except share and per share data)
PART III
PART IV
SIGNATURES
 EX-10.71 2 a2213180zex-10_71.htm EX 10.71

Exhibit 10.71

 

EXECUTION VERSION

 

 

GUARANTY

 

by

 

CLEAN ENERGY FUELS CORP.

 

as Guarantor,

 

in favor of

 

GENERAL ELECTRIC CAPITAL CORPORATION,

 

as Collateral Agent

 

 

Dated as of  November 7, 2012

 

 


 

TABLE OF CONTENTS

 

 

 

Page

 

ARTICLE I

 

 

DEFINITIONS AND INTERPRETATION

 

 

 

 

Section 1.1

Definitions

1

Section 1.2

Interpretation

2

Section 1.3

No Strict Construction

2

 

 

 

 

ARTICLE II

 

 

GUARANTY

 

 

 

 

Section 2.1

Guaranty

2

Section 2.2

Guaranty Absolute

3

Section 2.3

Waivers and Acknowledgments

4

Section 2.4

Subrogation

5

Section 2.5

Reinstatement

5

 

 

 

 

ARTICLE III

 

 

REPRESENTATIONS AND WARRANTIES

 

 

 

 

Section 3.1

Corporate Existence

5

Section 3.2

Power and Authority; Compliance with Law; Enforceability; Governmental Approvals

6

Section 3.3

Taxes

6

Section 3.4

Solvency

6

Section 3.5

Litigation

7

 

 

 

 

ARTICLE IV

 

 

COVENANTS

 

 

 

 

Section 4.1

Maintenance of Existence

7

Section 4.2

Compliance with Laws, Etc.

7

Section 4.3

Expenses

7

Section 4.4

Inspections

7

Section 4.5

Bankruptcy Filing, etc.

7

 

i


 

 

ARTICLE V

 

 

PERFORMANCE BY COLLATERAL AGENT OF GUARANTOR’S OBLIGATIONS

 

 

 

 

 

ARTICLE VI

 

 

REMEDIES; RIGHTS UPON EVENT OF DEFAULT

 

 

 

 

Section 6.1

Remedies

8

 

 

 

 

ARTICLE VII

 

 

NON-CIRCUMVENTION

 

 

 

 

 

ARTICLE VIII

 

 

MISCELLANEOUS

 

 

 

 

Section 8.1

Headings

9

Section 8.2

Modification in Writing

9

Section 8.3

Concerning the Collateral Agent

9

Section 8.4

Survival of Representations and Warranties

10

Section 8.5

No Third Party Beneficiaries

10

Section 8.6

No Waiver by Course of Conduct

11

Section 8.7

Successors and Assigns

11

Section 8.8

Termination; Release

11

Section 8.9

Incorporation by Reference

11

 

ii


 

GUARANTY

 

This GUARANTY (as amended, amended and restated, supplemented or otherwise modified from time to time, this “Guaranty”), dated as of November 7, 2012, is made by CLEAN ENERGY FUELS CORP., a Delaware corporation (the “Guarantor”), in favor of GENERAL ELECTRIC CAPITAL CORPORATION, as collateral agent (in such capacity, together with its successors and permitted assigns, the “Collateral Agent”), for the benefit of the Secured Parties (as defined in the Credit Agreement described below).

 

RECITALS

 

WHEREAS, the Guarantor is the sole owner of all of the equity interests of CLEAN ENERGY LNG HOLDINGS, LLC, a Delaware limited liability company (“Holdings”);

 

WHEREAS, Holdings is the sole owner of all of the equity interests of CLEAN ENERGY TRANCHE A LNG PLANT, LLC, a Delaware limited liability company (the “Tranche A Borrower”) and CLEAN ENERGY TRANCHE B LNG PLANT, LLC, a Delaware limited liability company (the “Tranche B Borrower”) and, together with the Tranche A Borrower, the “Borrowers”);

 

WHEREAS, the Borrowers intend to undertake the development, construction and ownership of two (2) micro-LNG facilities, each with a capacity of approximately 250,000 gallons per day;

 

WHEREAS, the Borrowers, the various financial institutions from time to time party thereto, as Lenders, General Electric Capital Corporation, as administrative agent, and the Collateral Agent have entered into a Credit Agreement dated as of November 7, 2012 (as the same may be amended, amended and restated, supplemented or otherwise modified from time to time, the “Credit Agreement”), providing for the making of Loans to the Borrowers as contemplated therein; and

 

WHEREAS, it is a condition precedent to the effectiveness of the Credit Agreement that the Guarantor have executed and delivered this Guaranty to the Collateral Agent.

 

NOW, THEREFORE, in consideration of the premises and to induce the Lenders, the Administrative Agent and the Collateral Agent to enter into the Credit Agreement and to induce the Lenders to make the Loans to the Borrowers thereunder, the Guarantor hereby agrees with the Collateral Agent as follows:

 

ARTICLE I
DEFINITIONS AND INTERPRETATION

 

Section 1.1                                    Definitions.

 

(a)                                 Terms used but not otherwise defined herein that are defined in the Credit Agreement shall have the meanings given to them in the Credit Agreement.

 

(b)                                 The following terms shall have the following meanings:

 

1


 

“Borrowers” shall have the meaning provided in the Recitals hereto and “Borrower” shall mean either of the Borrowers.

 

“Collateral Agent” shall have the meaning provided in the Preamble hereto.

 

“Credit Agreement” shall have the meaning provided in the Recitals hereto.

 

“Deficiency” shall have the meaning provided in Section 4.6 hereof.

 

“Guaranteed Obligations” shall have the meaning provided in Section 2.1 hereof.

 

“Guarantor” shall have the meaning provided in the Preamble hereto.

 

“Guaranty” shall have the meaning provided in the Preamble hereto.

 

“Holdings” shall have the meaning provided in the Recitals hereto.

 

“Related Person” means, with respect to any Person, each Affiliate of such Person and each director, officer, employee, agent, trustee, representative, attorney, accountant and each insurance, environmental, legal, financial and other advisor and other consultants and agents of or to such Person or any of its Affiliates, together with, if such Person is an Agent, each other Person or individual designated, nominated or otherwise mandated by or helping such Agent pursuant to and in accordance with Section 10.2 of the Credit Agreement or any comparable provision of any Finance Document.

 

“Tranche A Borrower” shall have the meaning provided in the Recitals hereto.

 

“Tranche B Borrower” shall have the meaning provided in the Recitals hereto.

 

Section 1.2                                    Interpretation.  Sections 1.2 and 1.3 of the Credit Agreement shall apply to this Guaranty as if set forth in this Guaranty, mutatis mutandis.

 

Section 1.3                                    No Strict Construction.  The parties hereto have participated jointly in the negotiation and drafting of this Guaranty.  If an ambiguity or question of intent or interpretation arises, this Guaranty shall be construed as if drafted jointly by the parties hereto and no presumption or burden of proof shall arise favoring or disfavoring any party by virtue of the authorship of any provisions of this Guaranty.

 

ARTICLE II
GUARANTY

 

Section 2.1                                    Guaranty.

 

The Guarantor hereby absolutely, unconditionally and irrevocably guarantees the punctual payment when due, whether at scheduled maturity or on any date of a required prepayment or by acceleration, demand or otherwise, of all Obligations of the Borrowers now or hereafter existing under or in respect of the Finance Documents (including, without limitation, any extensions, modifications, substitutions, amendments or renewals of any or all of the

 

2


 

foregoing Obligations), whether direct or indirect, absolute or contingent, and whether for principal, interest, premiums, fees, indemnities, contract causes of action, costs, expenses or otherwise (such Obligations being the “Guaranteed Obligations”), and agrees to pay any and all expenses (including, without limitation, fees and expenses of counsel) incurred by the Collateral Agent or any other Secured Party in enforcing any rights under this Guaranty or any other Finance Document.

 

Section 2.2                                    Guaranty Absolute.  The Guarantor guarantees that the Guaranteed Obligations will be paid strictly in accordance with the terms of the Finance Documents, regardless of any Law, regulation or order now or hereafter in effect in any jurisdiction affecting any of such terms or the rights of any Secured Party with respect thereto.  The guaranty by the Guarantor under this Guaranty is a guaranty of payment, and not of collection, and a debt of the Guarantor for its own account. The obligations of the Guarantor under or in respect of this Guaranty are independent of the Guaranteed Obligations or any other Obligations of the Borrowers under or in respect of the Finance Documents, and a separate action or actions may be brought and prosecuted against the Guarantor to enforce this Guaranty, irrespective of whether any action is brought against any Borrower or whether any Borrower is joined in any such action or actions.  The obligations of the Guarantor under this Guaranty and the rights of the Collateral Agent hereunder shall be irrevocable, absolute and unconditional irrespective of, and the Guarantor hereby irrevocably waives any defenses it may now have or hereafter acquire in any way relating to, any or all of the following:

 

(a)                                 any lack of validity or enforceability of any Transaction Document or any agreement or instrument relating thereto;

 

(b)                                 any change in the time, manner or place of payment of, or in any other term of, all or any of the Guaranteed Obligations or any Obligations, or any other amendment or waiver of or any consent to departure from any Transaction Document or any other agreement or instrument relating thereto, including, without limitation, any increase in the Guaranteed Obligations resulting from the extension of additional credit to the Borrowers;

 

(c)                                  any taking, exchange, release or non-perfection of any Collateral, or any taking, release or amendment or waiver of, or consent to departure from, any guaranty, for all or any of the Guaranteed Obligations or Obligations;

 

(d)                                 any manner of application of Collateral, or proceeds thereof, to all or any of the Guaranteed Obligations or Obligations, or any manner of sale or other disposition of any Collateral for all or any of the Guaranteed Obligations or Obligations or any other assets of the Borrowers;

 

(e)                                  any change, restructuring or termination of the corporate structure or existence of the Guarantor or the Borrowers;

 

(f)                                   any failure of any Secured Party to disclose to the Guarantor or the Borrowers any information relating to the business, condition (financial or otherwise), operations, performance, properties or prospects of the Guarantor or the Borrowers now or hereafter known to such

 

3


 

Secured Party (the Guarantor waiving any duty on the part of the Secured Parties to disclose such information);

 

(g)                                  the failure of any other Person to execute or deliver any other guaranty or agreement or the release or reduction of liability of any other guarantor or surety with respect to the Guaranteed Obligations or the Obligations;

 

(h)                                 any limitation on any party’s liability or obligations under any Finance Document or any invalidity or unenforceability, in whole or in part, of any such Finance Document;

 

(i)                                     any bankruptcy, insolvency, reorganization, composition, adjustment, dissolution, liquidation or other like proceeding relating to the Guarantor, the Borrowers, Holdings, or any action taken with respect to this Guaranty by any trustee or receiver, or by any court, in any such proceeding; or

 

(j)                                    any other circumstance (including, without limitation, any statute of limitations, but excluding the prior payment in full of the Guaranteed Obligations) or any existence of or reliance on any representation by any Secured Party that might otherwise constitute a defense available to, or a discharge of, the Borrowers or the Guarantor.

 

Section 2.3                                    Waivers and Acknowledgments

 

(a)                                 The Guarantor hereby unconditionally and irrevocably waives promptness, diligence, notice of acceptance, presentment, demand for performance, notice of nonperformance, default, acceleration, protest or dishonor and any other notice with respect to any of the Guaranteed Obligations and this Guaranty and any requirement that any Secured Party protect, secure, perfect or insure any Lien or any Property subject thereto or exhaust any right or take any action against the Borrowers or any other Person or any Collateral.

 

(b)                                 The Guarantor hereby unconditionally and irrevocably waives any right to revoke this Guaranty and acknowledges that this Guaranty is continuing in nature and applies to all Guaranteed Obligations, whether existing now or in the future, subject to Section 8.8.

 

(c)                                  The Guarantor hereby unconditionally and irrevocably waives (i) any defense arising by reason of any claim or defense based upon an election of remedies by any Secured Party that in any manner impairs, reduces, releases or otherwise adversely affects the subrogation, reimbursement, exoneration, contribution or indemnification rights of the Guarantor or other rights of the Guarantor to proceed against the Borrowers, any other guarantor or any other Person or any Collateral and (ii) any defense based on any right of set-off or counterclaim against or in respect of the obligations of the Guarantor hereunder.

 

(d)                                 The Guarantor acknowledges that after the occurrence and during the continuance of an Event of Default, the Collateral Agent may, without notice to or demand upon the Guarantor and without affecting the liability of the Guarantor under this Guaranty, foreclose under any Security Document by nonjudicial sale, and the Guarantor hereby waives any defense to the recovery by the Collateral Agent and the other Secured Parties against the Guarantor of any deficiency after such nonjudicial sale and any defense or benefits that may be afforded by Law.

 

4


 

The Guarantor acknowledges that it will receive substantial direct and indirect benefits from the financing arrangements contemplated by the Finance Documents and that the waivers set forth in Section 2.2 and this Section 2.3 are knowingly made in contemplation of such benefits.

 

Section 2.4                                    Subrogation.  Until the payment in full of the Guaranteed Obligations, the Guarantor hereby unconditionally and irrevocably agrees not to exercise any rights that it may now have or hereafter acquire against the Borrowers that arise from the existence, payment, performance or enforcement of the Guarantor’s obligations under or in respect of this Guaranty, including, without limitation, any right of subrogation, reimbursement, exoneration, contribution or indemnification and any right to participate in any claim or remedy of any Secured Party against the Borrowers or any Collateral, whether or not such claim, remedy or right arises in equity or under contract, statute or common law, including, without limitation, the right to take or receive from the Borrowers directly or indirectly, in cash or other Property or by set-off or in any other manner, payment or security on account of such claim, remedy or right.  If any amount shall be paid to the Guarantor in violation of the immediately preceding sentence at any time, such amount shall be received and held in trust for the benefit of the Secured Parties, shall be segregated from other Property and funds of the Guarantor and shall forthwith be paid or delivered to the Collateral Agent in the same form as so received (with any necessary endorsement or assignment) to be credited and applied to the Guaranteed Obligations and all other amounts payable under this Guaranty, whether matured or unmatured, in accordance with the terms of the Finance Documents, or to be held as Collateral for any Guaranteed Obligations or other amounts payable under this Guaranty thereafter arising.

 

Section 2.5                                    Reinstatement.  The Guarantor agrees that, if any payment made by any Finance Party or other Person and applied to the Guaranteed Obligations or Obligations is at any time annulled, avoided, set aside, rescinded, invalidated, declared to be fraudulent or preferential or otherwise required to be refunded or repaid, or the proceeds of any Collateral are required to be returned by any Secured Party to such Finance Party, its estate, trustee, receiver or any other party, including the Guarantor, under any bankruptcy law, state or federal law, common law or equitable cause, then, to the extent of such payment or repayment, such Guaranteed Obligations or Obligations shall be and remain in full force and effect, as fully as if such payment had never been made.

 

ARTICLE III
REPRESENTATIONS AND WARRANTIES

 

The Guarantor hereby represents and warrants as to itself as follows:

 

Section 3.1                                    Corporate Existence.  The Guarantor (a) is a corporation duly organized, validly existing and in good standing under the laws of the State of Delaware, (b) is duly qualified to do business as a foreign entity and in good standing under the laws of each jurisdiction in which it owns or leases Property or in which the conduct of its business requires it so to qualify, except the failure of which that could not reasonably be expected to result in a Material Adverse Effect, and (c) has all requisite power and authority to own or lease and operate its Properties, to carry on its business as contemplated by this Guaranty and to execute, deliver and perform each Transaction Document to which it is or will be a party.

 

5

 

Section 3.2                                    Power and Authority; Compliance with Law; Enforceability; Governmental Approvals.

 

(a)                                 The execution, delivery and performance by the Guarantor of each Transaction Document to which it is a party, and the transactions contemplated thereby (i) have been duly authorized by all necessary corporate action (including any necessary shareholder action), (ii) will not breach, contravene, violate, conflict with or constitute a default under (A) any of the Guarantor’s Charter Documents, (B) any material applicable Law, or (C) any material contract, loan agreement, indenture, mortgage, lease or other instrument to which the Guarantor is a party or by which it or any of its Properties may be bound or affected, including all Governmental Approvals and the Transaction Documents, and (iii) will not result in or require the creation or imposition of any Lien upon or with respect to any of the Properties of the Guarantor.

 

(b)                                 Each Transaction Document to which the Guarantor is a party has been duly executed and delivered by the Guarantor, is the legal, valid and binding obligation of the Guarantor and enforceable against the Guarantor in accordance with its terms, except as such enforcement may be limited by (i) the effect of bankruptcy, insolvency, reorganization, receivership, conservatorship, arrangement, moratorium or other laws affecting or relating to the rights of creditors generally, or (ii) the rules governing the availability of specific performance, injunctive relief or other equitable remedies and general principles of equity, regardless of whether considered in a proceeding in equity or at law.

 

(c)                                  No Governmental Approval has been, is or will be required to be obtained or made (i) in connection with the due execution, delivery or performance by the Guarantor of its obligations, and the exercise of its rights under, any of the Transaction Documents to which it is a party or any transaction contemplated thereby or (ii) to ensure the legality, validity and binding effect or enforceability of any such Transaction Document, except for the Governmental Approvals that have been duly obtained or made, were validly issued, and are in full force and effect, are final, not subject to any pending appeal, intervention or similar proceeding, are held in the name of the Guarantor and are free from conditions or requirements the compliance with which the Guarantor does not reasonably expect to be able to satisfy.  No event has occurred that could reasonably be expected to result in the revocation, termination or adverse modification of any such Governmental Approval or adversely affect any rights of the Guarantor under any such Governmental Approval.

 

(d)                                 The Guarantor is in compliance with its Charter Documents and is in compliance in all material respects with all Laws and Governmental Approvals applicable to it.

 

Section 3.3                                    Taxes.  The Guarantor has filed all federal, state and foreign income tax returns which are required to be filed by it, and the Guarantor has paid all taxes as shown on said returns and on all assessments received by it to the extent that such taxes have become due, except such taxes, if any, as are being contested in good faith and by proper proceedings as to which adequate reserves have been provided in accordance with GAAP.

 

Section 3.4                                    Solvency.  The Guarantor is Solvent.

 

6


 

Section 3.5                                    Litigation.  There is no action, suit, other legal proceeding, arbitral proceeding, inquiry or investigation pending or, to the best of the Guarantor’s knowledge, threatened, by or before any Governmental Authority or in any arbitral or other forum, nor any order, decree or judgment in effect, pending, or, to the best of the Guarantor’s knowledge, threatened, against or affecting the Guarantor or any of its Properties or rights, that relates to the Projects, to any of the Transaction Documents or to any of the transactions contemplated thereby.

 

ARTICLE IV
COVENANTS

 

The Guarantor covenants and agrees with the Collateral Agent that until the Guaranteed Obligations (other than contingent indemnity obligations in respect of which no claim has been made) are paid in full:

 

Section 4.1                                    Maintenance of Existence.  The Guarantor shall preserve and maintain its legal existence as a corporation under the laws of the State of Delaware and all of its licenses, rights, privileges and franchises necessary for the maintenance of its existence, and comply with its Charter Documents.

 

Section 4.2                                    Compliance with Laws, Etc.  The Guarantor shall conduct its business in compliance in all material respects with all Laws, including all Governmental Approvals applicable to it.

 

Section 4.3                                    Expenses.  The Guarantor will, upon demand, pay to the Collateral Agent the amount of any and all expenses, including the fees and expenses of its counsel and agents, which the Collateral Agent may incur in connection with the enforcement of this Guaranty pursuant to the exercise or enforcement of any of the rights of the Collateral Agent hereunder after the occurrence and during the continuance of an Event of Default or the failure by the Guarantor to perform or observe any of the provisions hereof, together with interest thereon at the Default Rate.  Any amounts payable by the Guarantor pursuant to this Section 4.3 shall be payable on demand and shall constitute Guaranteed Obligations.

 

Section 4.4                                    Inspections.  The Guarantor shall permit representatives of the Collateral Agent or any Secured Party (coordinated through the Administrative Agent) to make, or cause to be made, inspections and audits of any books, records and papers of the Guarantor relevant to the transactions contemplated hereby and to make extracts therefrom upon reasonable notice, and at all such reasonable times as the Collateral Agent or any Secured Party (coordinated through the Administrative Agent) may reasonably require. Notwithstanding the foregoing, the Guarantor shall bear the costs of only two inspections or audits per year, unless an Event of Default has occurred and is continuing, in which case the Guarantor shall bear the cost of all such inspections or audits.

 

Section 4.5                                    Bankruptcy Filing, etc.  The Guarantor shall not authorize, seek to cause or permit Holdings or a Borrower to commence a voluntary case or other voluntary proceeding seeking liquidation, reorganization or other relief with respect to Holdings or such Borrower or its debts under any bankruptcy, insolvency or other similar law now or hereafter in effect or

 

7


 

seeking the appointment of a trustee, receiver, liquidator, custodian or other similar official of Holdings or a Borrower or any substantial part of its Property or to consent to any such relief or to the appointment of or taking possession by any such official in an involuntary case or other proceeding commenced against Holdings or a Borrower, or to make a general assignment for the benefit of creditors.

 

ARTICLE V
PERFORMANCE BY COLLATERAL AGENT OF GUARANTOR’S OBLIGATIONS

 

If the Guarantor fails to perform or comply with any of its agreements or obligations contained herein, then the Collateral Agent may (but shall not be obligated to) itself elect to perform or comply, or otherwise cause performance or compliance, with such agreement or obligation, and the expenses of the Collateral Agent incurred in connection with such performance or compliance, together with interest thereon at the Default Rate, shall be payable by the Guarantor to the Collateral Agent on demand.

 

ARTICLE VI
REMEDIES; RIGHTS UPON EVENT OF DEFAULT

 

Section 6.1                                    Remedies

 

(a)                                 During the continuance of an Event of Default, the Collateral Agent may exercise, in addition to all other rights and remedies granted to it in this Guaranty and in any other instrument or agreement securing, evidencing or relating to any Obligation, any and all rights and remedies under any Law.

 

(b)                                 Neither the Collateral Agent nor any other Secured Party shall be required to make any demand upon, or pursue or exhaust any right or remedy against, the Guarantor, any other Finance Party or any other Person with respect to the payment of the Obligations or any direct or indirect guaranty thereof.  All of the rights and remedies of the Collateral Agent and any other Secured Party under any Finance Document shall be cumulative, may be exercised individually or concurrently and are not exclusive of any other rights or remedies provided by any Law.  To the extent it may lawfully do so, the Guarantor absolutely and irrevocably waives and relinquishes the benefit and advantage of, and covenants not to assert against the Collateral Agent or any other Secured Party, any valuation, stay, appraisement, extension, redemption or similar laws and any and all rights or defenses it may have as a surety, now or hereafter existing, arising out of the exercise by them of any rights hereunder.

 

ARTICLE VII
NON-CIRCUMVENTION

 

The Guarantor acknowledges that the Lenders have expended substantial time, effort and resources and have foregone, or accepted reductions in, upfront and other customary fees and compensation for work performed and obligations undertaken in connection with the negotiation, execution and effectiveness of the Financing Documents.   In consideration of the foregoing and other good and valuable consideration the receipt and adequacy of which are hereby acknowledged, the Guarantor hereby agrees that, prior to the earlier of (a) the date the Holders (as defined in the Warrant) are entitled to exercise the Warrants for the total number of Shares (as defined in the

 

8


 

Warrant) purchasable thereunder and (b) December 31, 2014, and notwithstanding the right of a Borrower to reduce or terminate any applicable Commitment or prepay or repay any Obligation pursuant to the Credit Agreement, it shall not, and shall not authorize or permit any of the other Finance Parties or any of its or their Affiliates to, directly or indirectly, use the proceeds of any  financing (regardless of the form of capital used or the structure employed) other than the Tranche A Loans, the Tranche B Loans and the related Equity Contributions to finance the construction of any new liquefied natural gas production facility, unless the Guarantor has otherwise agreed to permit the Holders to exercise the Warrants for all remaining Shares purchasable thereunder. For the avoidance of doubt, the provisions of this Article VII shall not restrict:

 

1.              Any financing of existing LNG facilities owned by the Guarantor or any of its Subsidiaries;

 

2.              Any financing of expansions at existing LNG facilities owned by the Guarantor or any of its Subsidiaries;

 

3.              Any investment made by the Guarantor for [*****]; or

 

4.              Any investment made by the Guarantor or any of its Subsidiaries in [*****] where (i) such investment is made [*****] and with [*****], (ii) the [*****] and (iii) subsequent to such investment being made, [*****].

 

ARTICLE VIII
MISCELLANEOUS

 

Section 8.1                                    Headings.  The headings of the various Sections herein are for convenience of reference only and shall not define or limit any of the terms or provisions hereof.

 

Section 8.2                                    Modification in Writing.  No amendment, modification, supplement, termination, or waiver of or to any provision hereof, nor consent to any departure by the Guarantor therefrom, shall be effective unless in writing and signed by the Collateral Agent and, other than with respect to waivers of the Guarantor’s obligations hereunder, the Guarantor.  Any amendment, modification, or supplement of or to any provision hereof, any waiver of any provision hereof, and any consent to any departure by the Guarantor from the terms of any provision hereof in each case shall be effective only in the specific instance and for the specific purpose for which made or given.  Except where notice is specifically required by this Guaranty or any other document evidencing the Guaranteed Obligations, no notice to or demand on the Guarantor in any case shall entitle the Guarantor to any other or further notice or demand in similar or other circumstances.

 

Section 8.3                                    Concerning the Collateral Agent.

 

(a)                                 The Collateral Agent has been appointed as Collateral Agent pursuant to the Credit Agreement.  The actions of the Collateral Agent hereunder are subject to the provisions of

 

[*****]      Confidential portions of this document have been redacted and filed separately with the Securities and Exchange Commission.

 

9


 

the Credit Agreement.  The Collateral Agent shall have the right hereunder to (i) execute and deliver the Finance Documents and accept delivery thereof on the Secured Parties’ behalf from the Guarantor, (ii) take such action on the Secured Parties’ behalf and to exercise all rights, powers and remedies and perform the duties as are expressly delegated to the Collateral Agent under such Finance Documents and (iii) exercise such powers as are reasonably incidental thereto.  The Collateral Agent may employ agents and attorneys-in-fact in connection herewith and shall not be liable for the negligence or misconduct of any such agents or attorneys-in-fact selected by it in good faith.  The Collateral Agent may resign and a successor Collateral Agent may be appointed in the manner provided in the Credit Agreement.  Upon the acceptance of any appointment as the Collateral Agent by a successor Collateral Agent, that successor Collateral Agent shall thereupon succeed to and become vested with all the rights, powers, privileges and duties of the retiring Collateral Agent under this Guaranty, and the retiring Collateral Agent shall thereupon be discharged from its duties and obligations under this Guaranty.  After any retiring Collateral Agent’s resignation, the provisions hereof shall inure to its benefit as to any actions taken or omitted to be taken by it under this Guaranty while it was the Collateral Agent.

 

(b)                                 None of the Collateral Agent and its Related Persons shall be liable for any action taken or omitted to be taken by any of them under or in connection with any Finance Document, and the Guarantor hereby waives and shall not assert any right, claim or cause of action based thereon, except to the extent of liabilities resulting primarily from the gross negligence or willful misconduct of the Collateral Agent or, as the case may be, such Related Person (each as determined in a final, non-appealable judgment by a court of competent jurisdiction) in connection with the duties expressly set forth herein.  Without limiting the foregoing, the Collateral Agent shall not be responsible or otherwise incur liability for any action or omission taken in reliance upon the instructions of the Required Lenders or for the actions or omissions of any of its Related Persons selected with reasonable care (other than employees, officers and directors of the Collateral Agent, when acting on behalf of the Collateral Agent), and the Guarantor hereby waives and agrees not to assert any right, claim or cause of action it might have against the Collateral Agent based thereon.

 

(c)                                  The Collateral Agent shall be entitled to rely upon any written notice, statement, certificate, order or other document or any telephone message reasonably believed by it to be genuine and correct and to have been signed, sent or made by the proper Person, and, with respect to all matters pertaining to this Guaranty and its duties hereunder, upon advice of counsel selected by it.

 

Section 8.4                                    Survival of Representations and Warranties.  All representations and warranties of the Guarantor contained or incorporated by reference herein or made in writing by the Guarantor in connection herewith shall survive the execution and delivery of this Guaranty regardless of any investigation made by any Secured Party or on its behalf.

 

Section 8.5                                    No Third Party Beneficiaries.  The agreements of the parties hereto are solely for the benefit of the Guarantor, the Collateral Agent and the other Secured Parties and their respective successors and permitted assigns and no other Person shall have any rights hereunder.

 

10


 

Section 8.6                                    No Waiver by Course of Conduct.  No Secured Party shall by any act, delay, indulgence, omission or otherwise be deemed to have waived any right or remedy hereunder or to have acquiesced in any Default or Event of Default.  No failure to exercise, nor any delay in exercising, on the part of any Secured Party, any right, power or privilege hereunder shall operate as a waiver thereof.  No single or partial exercise of any right, power or privilege hereunder shall preclude any other or further exercise thereof or the exercise of any other right, power or privilege.  A waiver by any Secured Party of any right or remedy hereunder on any one occasion shall not be construed as a bar to any right or remedy that such Secured Party would otherwise have on any future occasion.

 

Section 8.7                                    Successors and Assigns.  This Guaranty shall be binding upon the successors and permitted assigns of the Guarantor and shall inure to the benefit of each Secured Party and their successors and permitted assigns; provided, however, that the Guarantor may not assign, transfer or delegate any of its rights or obligations under this Guaranty without the prior written consent of the Collateral Agent.

 

Section 8.8                                    Termination; Release.  When all the Guaranteed Obligations have been paid in full (other than contingent indemnity obligations in respect of which no claim has been made) and the Commitments of the Lenders to make any Loans under the Credit Agreement shall have expired or been sooner terminated in accordance with the provisions of the Credit Agreement, this Guaranty (other than Article VII) shall terminate.

 

Section 8.9                                    Incorporation by Reference.  The following sections of the Credit Agreement are hereby incorporated herein by reference, mutatis mutandis: Section 11.3 (Notices), Section 11.8 (No Immunity), Section 11.9 (Counterparts), Section 11.13 (Waiver of Jury Trial), Section 11.15 (Severability), Section 11.18 (Governing Law; Submission to Jurisdiction), Section 11.20 (Complete Agreement) and Section 11.21 (No Strict Construction).

 

*     *     *

 

11


 

IN WITNESS WHEREOF, the Guarantor and the Collateral Agent have caused this Guaranty to be duly executed and delivered as of the date first written above.

 

 

 

Guarantor:

 

 

 

CLEAN ENERGY FUELS CORP.

 

 

 

 

 

By:

/s/ Andrew J. Littlefair

 

 

Name:

Andrew J. Littlefair

 

 

Title:

President & Chief Executive Officer

 

 

 

Collateral Agent:

 

 

 

GENERAL ELECTRIC CAPITAL CORPORATION

 

 

 

 

 

By:

/s/ Tyson Yates

 

 

Name:

Tyson Yates

 

 

Title:

Authorized Signatory

 

Signature Page to the Sponsor Guaranty

 


 EX-10.75 3 a2213180zex-10_75.htm EX 10.75

EXHIBIT 10.75

 

SECOND AMENDMENT TO

AMENDED AND RESTATED EMPLOYMENT AGREEMENT

 

This Second Amendment (this “Amendment”) is made and entered into this 12th day of December, 2012 (the “Effective Date”), by and between Andrew J. Littlefair (“Employee”) and Clean Energy Fuels Corp., a Delaware corporation (the “Company”) (collectively, the “Parties”).

 

WHEREAS, the Parties previously entered into an amended and restated employment agreement effective as of December 31, 2008 (the “Agreement”), which was previously amended on February 17, 2012 (collectively, the “Employment Agreement”); and

 

WHEREAS, the Parties desire to further amend the terms and conditions of the Employment Agreement pursuant to this Amendment to reflect certain changes necessary to comply with applicable law.

 

NOW, THEREFORE, in consideration of the mutual promises herein made, the sufficiency of which are expressly acknowledged, the Parties hereby agree that the Employment Agreement shall be further amended as follows, effective as of the Effective Date:

 

1.     By replacing the phrase “during the first 75 days of the fiscal year” where it appears in Section 4(b), and the phrase “on or before the 75th day” where it appears in Section 5(a)(3), with the phrase “no later than March 15th”.

 

2.     By replacing the penultimate sentence of Section 5(d), and the final sentence of both Section 5(e)(ii) and Section 5(f)(i), with the following sentence:

 

“The cash Severance Benefits shall be paid to Employee as described in Section 5(j).”

 

3.     By inserting the following sentence at the end of Section 5(f)(ii):

 

“Notwithstanding anything in this Agreement to the contrary, to the extent that any of the payments or benefits provided under this Agreement are reduced in accordance with the provisions of this Section 5(f)(ii), payments and benefits that do not constitute nonqualified deferred compensation within the meaning of Code Section 409A shall be reduced first, and any reduction shall be made in a manner consistent with the requirements of Code Section 409A.”

 

4.     By inserting the following sentence at the end of Section 5(j):

 

“If the Release is executed and delivered and no longer subject to revocation as provided herein, then any cash severance benefits shall be paid on the 90th day following the termination of Employee’s employment (other than the Pro-Rated Incentive Compensation, which shall be paid as specified in Section 5(a)), except to the extent that such payments are further delayed pursuant to the application of Section 5(h).”

 

5.     By inserting the following as a new Section 7(q):

 

“q.           Code Section 409A.

 

i.              General.  It is the intent of Employer and Employee that the payments and benefits under this Agreement shall comply with or be exempt from Code Section 409A, and accordingly, to the maximum extent permitted, this Agreement shall be interpreted to be in compliance with or exempt from Code Section 409A.  In no event whatsoever shall Employer be liable for any additional tax, interest or penalty that may be imposed on Employee pursuant to Code Section 409A or for any damages for failing to comply with Code Section 409A.  All references to Code Section 409A shall be interpreted to include Code Section 409A and all regulations and guidance promulgated thereunder.

 


 

ii.             Reimbursements and In-Kind Benefits. To the extent any reimbursements or in-kind benefits under this Agreement are subject to Code Section 409A, (A) all such expenses or other reimbursements under this Agreement shall be made on or prior to the last day of the taxable year following the taxable year in which such expenses were incurred by Employee; (B) any right to such reimbursement or in-kind benefits is not subject to liquidation or exchange for another benefit; and (C) no such reimbursement, expenses eligible for reimbursement, or in-kind benefits provided in any taxable year shall in any way affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other taxable year.

 

iii.            Offsets.   Notwithstanding any other provision of this Agreement to the contrary, in no event shall any payment under this Agreement that is subject to Code Section 409A be subject to offset, counterclaim, or recoupment by any other amount unless otherwise permitted by Code Section 409A.”

 

As amended hereby, the Employment Agreement shall be and remain in full force and effect.

 

[signature page follows]

 


 

IN WITNESS WHEREOF, the Parties hereto have duly executed this Amendment on and as of the date first set forth above.

 

 

 

CLEAN ENERGY FUELS CORP.

 

 

 

 

 

 

 

By:

/s/ Richard R. Wheeler

 

Name:

Richard R. Wheeler

 

Title:

Chief Financial Officer

 

 

 

 

 

 

 

EMPLOYEE

 

 

 

 

 

/s/ Andrew J. Littlefair

 

Andrew J. Littlefair

 


 EX-10.76 4 a2213180zex-10_76.htm EX 10.76

EXHIBIT 10.76

 

SECOND AMENDMENT TO

AMENDED AND RESTATED EMPLOYMENT AGREEMENT

 

This Second Amendment (this “Amendment”) is made and entered into this 12th day of December, 2012 (the “Effective Date”), by and between Richard R. Wheeler (“Employee”) and Clean Energy Fuels Corp., a Delaware corporation (the “Company”) (collectively, the “Parties”).

 

WHEREAS, the Parties previously entered into an amended and restated employment agreement effective as of December 31, 2008 (the “Agreement”), which was previously amended on February 17, 2012 (collectively, the “Employment Agreement”); and

 

WHEREAS, the Parties desire to further amend the terms and conditions of the Employment Agreement pursuant to this Amendment to reflect certain changes necessary to comply with applicable law.

 

NOW, THEREFORE, in consideration of the mutual promises herein made, the sufficiency of which are expressly acknowledged, the Parties hereby agree that the Employment Agreement shall be further amended as follows, effective as of the Effective Date:

 

1.              By replacing the phrase “during the first 75 days of the fiscal year” where it appears in Section 4(b), and the phrase “on or before the 75th day” where it appears in Section 5(a)(3), with the phrase “no later than March 15th”.

 

2.              By replacing the penultimate sentence of Section 5(d), and the final sentence of both Section 5(e)(ii) and Section 5(f)(i), with the following sentence:

 

“The cash Severance Benefits shall be paid to Employee as described in Section 5(j).”

 

3.              By inserting the following sentence at the end of Section 5(f)(ii):

 

“Notwithstanding anything in this Agreement to the contrary, to the extent that any of the payments or benefits provided under this Agreement are reduced in accordance with the provisions of this Section 5(f)(ii), payments and benefits that do not constitute nonqualified deferred compensation within the meaning of Code Section 409A shall be reduced first, and any reduction shall be made in a manner consistent with the requirements of Code Section 409A.”

 

4.              By inserting the following sentence at the end of Section 5(j):

 

“If the Release is executed and delivered and no longer subject to revocation as provided herein, then any cash severance benefits shall be paid on the 90th day following the termination of Employee’s employment (other than the Pro-Rated Incentive Compensation, which shall be paid as specified in Section 5(a)), except to the extent that such payments are further delayed pursuant to the application of Section 5(h).”

 

5.              By inserting the following as a new Section 7(q):

 

“q.         Code Section 409A.

 

i.                                          General.  It is the intent of Employer and Employee that the payments and benefits under this Agreement shall comply with or be exempt from Code Section 409A, and accordingly, to the maximum extent permitted, this Agreement shall be interpreted to be in compliance with or exempt from Code Section 409A.  In no event whatsoever shall Employer be liable for any additional tax, interest or penalty that may be imposed on Employee pursuant to Code Section 409A or for any damages for failing to comply with Code Section 409A.  All references to Code Section 409A shall be interpreted to include Code Section 409A and all regulations and guidance promulgated thereunder.

 


 

ii.                                       Reimbursements and In-Kind Benefits. To the extent any reimbursements or in-kind benefits under this Agreement are subject to Code Section 409A, (A) all such expenses or other reimbursements under this Agreement shall be made on or prior to the last day of the taxable year following the taxable year in which such expenses were incurred by Employee; (B) any right to such reimbursement or in-kind benefits is not subject to liquidation or exchange for another benefit; and (C) no such reimbursement, expenses eligible for reimbursement, or in-kind benefits provided in any taxable year shall in any way affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other taxable year.

 

iii.                                    Offsets.  Notwithstanding any other provision of this Agreement to the contrary, in no event shall any payment under this Agreement that is subject to Code Section 409A be subject to offset, counterclaim, or recoupment by any other amount unless otherwise permitted by Code Section 409A.”

 

As amended hereby, the Employment Agreement shall be and remain in full force and effect.

 

[signature page follows]

 


 

IN WITNESS WHEREOF, the Parties hereto have duly executed this Amendment on and as of the date first set forth above.

 

 

 

CLEAN ENERGY FUELS CORP.

 

 

 

 

 

 

By:

/s/ Andrew J. Littlefair

 

Name:

Andrew J. Littlefair

 

Title:

President & CEO

 

 

 

 

 

 

 

EMPLOYEE

 

 

 

 

 

/s/ Richard R. Wheeler

 

Richard R. Wheeler

 


 EX-10.77 5 a2213180zex-10_77.htm EX 10.77

EXHIBIT 10.77

 

SECOND AMENDMENT TO

AMENDED AND RESTATED EMPLOYMENT AGREEMENT

 

This Second Amendment (this “Amendment”) is made and entered into this 12th day of December, 2012 (the “Effective Date”), by and between Mitchell W. Pratt (“Employee”) and Clean Energy Fuels Corp., a Delaware corporation (the “Company”) (collectively, the “Parties”).

 

WHEREAS, the Parties previously entered into an amended and restated employment agreement effective as of December 31, 2008 (the “Agreement”), which was previously amended on February 17, 2012 (collectively, the “Employment Agreement”); and

 

WHEREAS, the Parties desire to further amend the terms and conditions of the Employment Agreement pursuant to this Amendment to reflect certain changes necessary to comply with applicable law.

 

NOW, THEREFORE, in consideration of the mutual promises herein made, the sufficiency of which are expressly acknowledged, the Parties hereby agree that the Employment Agreement shall be further amended as follows, effective as of the Effective Date:

 

1.              By replacing the phrase “during the first 75 days of the fiscal year” where it appears in Section 4(b), and the phrase “on or before the 75th day” where it appears in Section 5(a)(3), with the phrase “no later than March 15th”.

 

2.              By replacing the penultimate sentence of Section 5(d), and the final sentence of both Section 5(e)(ii) and Section 5(f)(i), with the following sentence:

 

“The cash Severance Benefits shall be paid to Employee as described in Section 5(j).”

 

3.              By inserting the following sentence at the end of Section 5(f)(ii):

 

“Notwithstanding anything in this Agreement to the contrary, to the extent that any of the payments or benefits provided under this Agreement are reduced in accordance with the provisions of this Section 5(f)(ii), payments and benefits that do not constitute nonqualified deferred compensation within the meaning of Code Section 409A shall be reduced first, and any reduction shall be made in a manner consistent with the requirements of Code Section 409A.”

 

4.              By inserting the following sentence at the end of Section 5(j):

 

“If the Release is executed and delivered and no longer subject to revocation as provided herein, then any cash severance benefits shall be paid on the 90th day following the termination of Employee’s employment (other than the Pro-Rated Incentive Compensation, which shall be paid as specified in Section 5(a)), except to the extent that such payments are further delayed pursuant to the application of Section 5(h).”

 

5.              By inserting the following as a new Section 7(q):

 

“q.         Code Section 409A.

 

i.                                          General.  It is the intent of Employer and Employee that the payments and benefits under this Agreement shall comply with or be exempt from Code Section 409A, and accordingly, to the maximum extent permitted, this Agreement shall be interpreted to be in compliance with or exempt from Code Section 409A.  In no event whatsoever shall Employer be liable for any additional tax, interest or penalty that may be imposed on Employee pursuant to Code Section 409A or for any damages for failing to comply with Code Section 409A.  All references to Code Section 409A shall be interpreted to include Code Section 409A and all regulations and guidance promulgated thereunder.

 


 

ii.                                       Reimbursements and In-Kind Benefits. To the extent any reimbursements or in-kind benefits under this Agreement are subject to Code Section 409A, (A) all such expenses or other reimbursements under this Agreement shall be made on or prior to the last day of the taxable year following the taxable year in which such expenses were incurred by Employee; (B) any right to such reimbursement or in-kind benefits is not subject to liquidation or exchange for another benefit; and (C) no such reimbursement, expenses eligible for reimbursement, or in-kind benefits provided in any taxable year shall in any way affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other taxable year.

 

iii.                                    Offsets.  Notwithstanding any other provision of this Agreement to the contrary, in no event shall any payment under this Agreement that is subject to Code Section 409A be subject to offset, counterclaim, or recoupment by any other amount unless otherwise permitted by Code Section 409A.”

 

As amended hereby, the Employment Agreement shall be and remain in full force and effect.

 

[signature page follows]

 


 

IN WITNESS WHEREOF, the Parties hereto have duly executed this Amendment on and as of the date first set forth above.

 

 

 

CLEAN ENERGY FUELS CORP.

 

 

 

 

 

By:

/s/ Andrew J. Littlefair

 

Name:

Andrew J. Littlefair

 

Title:

President & CEO

 

 

 

 

 

EMPLOYEE

 

 

 

 

 

/s/ Mitchell W. Pratt

 

Mitchell W. Pratt

 


 EX-10.78 6 a2213180zex-10_78.htm EX 10.78

EXHIBIT 10.78

 

SECOND AMENDMENT TO

AMENDED AND RESTATED EMPLOYMENT AGREEMENT

 

This Second Amendment (this “Amendment”) is made and entered into this 12th day of December, 2012 (the “Effective Date”), by and between James N. Harger (“Employee”) and Clean Energy Fuels Corp., a Delaware corporation (the “Company”) (collectively, the “Parties”).

 

WHEREAS, the Parties previously entered into an amended and restated employment agreement effective as of December 31, 2008 (the “Agreement”), which was previously amended on February 17, 2012 (collectively, the “Employment Agreement”); and

 

WHEREAS, the Parties desire to further amend the terms and conditions of the Employment Agreement pursuant to this Amendment to reflect certain changes necessary to comply with applicable law.

 

NOW, THEREFORE, in consideration of the mutual promises herein made, the sufficiency of which are expressly acknowledged, the Parties hereby agree that the Employment Agreement shall be further amended as follows, effective as of the Effective Date:

 

1.              By replacing the phrase “during the first 75 days of the fiscal year” where it appears in Section 4(b), and the phrase “on or before the 75th day” where it appears in Section 5(a)(3), with the phrase “no later than March 15th”.

 

2.              By replacing the penultimate sentence of Section 5(d), and the final sentence of both Section 5(e)(ii) and Section 5(f)(i), with the following sentence:

 

“The cash Severance Benefits shall be paid to Employee as described in Section 5(j).”

 

3.              By inserting the following sentence at the end of Section 5(f)(ii):

 

“Notwithstanding anything in this Agreement to the contrary, to the extent that any of the payments or benefits provided under this Agreement are reduced in accordance with the provisions of this Section 5(f)(ii), payments and benefits that do not constitute nonqualified deferred compensation within the meaning of Code Section 409A shall be reduced first, and any reduction shall be made in a manner consistent with the requirements of Code Section 409A.”

 

4.              By inserting the following sentence at the end of Section 5(j):

 

“If the Release is executed and delivered and no longer subject to revocation as provided herein, then any cash severance benefits shall be paid on the 90th day following the termination of Employee’s employment (other than the Pro-Rated Incentive Compensation, which shall be paid as specified in Section 5(a)), except to the extent that such payments are further delayed pursuant to the application of Section 5(h).”

 

5.              By inserting the following as a new Section 7(q):

 

“q.         Code Section 409A.

 

i.                                          General.  It is the intent of Employer and Employee that the payments and benefits under this Agreement shall comply with or be exempt from Code Section 409A, and accordingly, to the maximum extent permitted, this Agreement shall be interpreted to be in compliance with or exempt from Code Section 409A.  In no event whatsoever shall Employer be liable for any additional tax, interest or penalty that may be imposed on Employee pursuant to Code Section 409A or for any damages for failing to comply with Code Section 409A.  All references to Code Section 409A shall be interpreted to include Code Section 409A and all regulations and guidance promulgated thereunder.

 


 

ii.                                       Reimbursements and In-Kind Benefits. To the extent any reimbursements or in-kind benefits under this Agreement are subject to Code Section 409A, (A) all such expenses or other reimbursements under this Agreement shall be made on or prior to the last day of the taxable year following the taxable year in which such expenses were incurred by Employee; (B) any right to such reimbursement or in-kind benefits is not subject to liquidation or exchange for another benefit; and (C) no such reimbursement, expenses eligible for reimbursement, or in-kind benefits provided in any taxable year shall in any way affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other taxable year.

 

iii.                                    Offsets.  Notwithstanding any other provision of this Agreement to the contrary, in no event shall any payment under this Agreement that is subject to Code Section 409A be subject to offset, counterclaim, or recoupment by any other amount unless otherwise permitted by Code Section 409A.”

 

As amended hereby, the Employment Agreement shall be and remain in full force and effect.

 

[signature page follows]

 


 

IN WITNESS WHEREOF, the Parties hereto have duly executed this Amendment on and as of the date first set forth above.

 

 

 

 

 

 

 

 

CLEAN ENERGY FUELS CORP.

 

 

 

 

 

 

 

 

 

 

 

 

 

By:

/s/ Andrew J. Littlefair

 

 

 

Name:

Andrew J. Littlefair

 

 

 

Title:

President & CEO

 

 

 

 

 

 

 

 

 

 

 

 

 

EMPLOYEE

 

 

 

 

 

 

 

 

 

 

 

/s/ James N. Harger

 

 

 

James N. Harger

 

 


 EX-10.79 7 a2213180zex-10_79.htm EX 10.79

EXHIBIT 10.79

 

SECOND AMENDMENT TO EMPLOYMENT AGREEMENT

 

This Second Amendment (this “Amendment”) is made and entered into this 12th day of December, 2012 (the “Effective Date”), by and between Barclay F. Corbus (“Employee”) and Clean Energy Fuels Corp., a Delaware corporation (the “Company”) (collectively, the “Parties”).

 

WHEREAS, the Parties previously entered into an employment agreement effective as of February 17, 2010 (the “Agreement”), which was previously amended on February 17, 2012 (collectively, the “Employment Agreement”); and

 

WHEREAS, the Parties desire to further amend the terms and conditions of the Employment Agreement pursuant to this Amendment to reflect certain changes necessary to comply with applicable law.

 

NOW, THEREFORE, in consideration of the mutual promises herein made, the sufficiency of which are expressly acknowledged, the Parties hereby agree that the Employment Agreement shall be further amended as follows, effective as of the Effective Date:

 

1.              By replacing the phrase “during the ninety (90) days of the fiscal year” where it appears in Section 4(b), and the phrase “on or before the day that is ninety (90) days” where it appears in Section 5(a)(3), with the phrase “no later than March 15th”.

 

2.              By replacing the penultimate sentence of Section 5(d), and the final sentence of both Section 5(e)(ii) and Section 5(f)(i), with the following sentence:

 

“The cash Severance Benefits shall be paid to Employee as described in Section 5(i).”

 

3.              By inserting the following sentence at the end of Section 5(f)(ii):

 

“Notwithstanding anything in this Agreement to the contrary, to the extent that any of the payments or benefits provided under this Agreement are reduced in accordance with the provisions of this Section 5(f)(ii), payments and benefits that do not constitute nonqualified deferred compensation within the meaning of Code Section 409A shall be reduced first, and any reduction shall be made in a manner consistent with the requirements of Code Section 409A.”

 

4.              By inserting the following sentence at the end of Section 5(i):

 

“If the Release is executed and delivered and no longer subject to revocation as provided herein, then any cash severance benefits shall be paid on the 90th day following the termination of Employee’s employment (other than the Pro-Rated Incentive Compensation, which shall be paid as specified in Section 5(a)), except to the extent that such payments are further delayed pursuant to the application of Section 5(g).”

 

5.              By inserting the following as a new Section 7(q):

 

“q.         Code Section 409A.

 

i.                                          General.  It is the intent of Employer and Employee that the payments and benefits under this Agreement shall comply with or be exempt from Code Section 409A, and accordingly, to the maximum extent permitted, this Agreement shall be interpreted to be in compliance with or exempt from Code Section 409A.  In no event whatsoever shall Employer be liable for any additional tax, interest or penalty that may be imposed on Employee pursuant to Code Section 409A or for any damages for failing to comply with Code Section 409A.  All references to Code Section 409A shall be interpreted to include Code Section 409A and all regulations and guidance promulgated thereunder.

 


 

ii.                                       Reimbursements and In-Kind Benefits. To the extent any reimbursements or in-kind benefits under this Agreement are subject to Code Section 409A, (A) all such expenses or other reimbursements under this Agreement shall be made on or prior to the last day of the taxable year following the taxable year in which such expenses were incurred by Employee; (B) any right to such reimbursement or in-kind benefits is not subject to liquidation or exchange for another benefit; and (C) no such reimbursement, expenses eligible for reimbursement, or in-kind benefits provided in any taxable year shall in any way affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other taxable year.

 

iii.                                    Offsets.  Notwithstanding any other provision of this Agreement to the contrary, in no event shall any payment under this Agreement that is subject to Code Section 409A be subject to offset, counterclaim, or recoupment by any other amount unless otherwise permitted by Code Section 409A.”

 

As amended hereby, the Employment Agreement shall be and remain in full force and effect.

 

[signature page follows]

 


 

IN WITNESS WHEREOF, the Parties hereto have duly executed this Amendment on and as of the date first set forth above.

 

 

 

CLEAN ENERGY FUELS CORP.

 

 

 

 

 

 

By:

/s/ Andrew J. Littlefair

 

Name:

Andrew J. Littlefair

 

Title:

President & CEO

 

 

 

 

 

 

 

EMPLOYEE

 

 

 

 

 

/s/ Barclay F. Corbus

 

Barclay F. Corbus

 


 EX-21.1 8 a2213180zex-21_1.htm EX 21.1
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Exhibit 21.1


CLEAN ENERGY FUELS CORP. SUBSIDIARIES
as of December 31, 2012

Name of Subsidiary
  State or Country of Incorporation or Organization
I.M.W. CNG Bangladesh Ltd.    Bangladesh
0884808 B.C. Ltd.    British Columbia
0886011 B.C. Ltd.    British Columbia
Clean Energy Compression Corp.    British Columbia
Clean Energy Fueling Services Corp.    British Columbia
Clean Energy   California
Clean Energy Finance, LLC   California
Clean Energy LNG, LLC   California
IMW Compressors (Shanghai) Co., Ltd.    China
IMW Colombia Ltd.    Colombia
Natural Fuels Company LLC   Colorado
Airport CNG, LLC   Delaware
Blue Energy General LLC   Delaware
Blue Energy Limited LLC   Delaware
CE Natural Gas Fueling Services, LLC   Delaware
Clean Energy LNG Holdings, LLC   Delaware
Clean Energy National LNG Corridor, LLC   Delaware
Clean Energy Renewable Fuels, LLC   Delaware
Clean Energy & Technologies LLC   Delaware
Clean Energy Tranche A LNG Plant, LLC   Delaware
Clean Energy Tranche B LNG Plant, LLC   Delaware
Dallas Clean Energy McCommas Bluff, LLC   Delaware
Dallas Clean Energy, LLC*   Delaware
BAF Technologies, Inc.    Kentucky
Canton Renewables, LLC   Michigan
Clean Energy del Peru S.R.L.*   Peru
IMW del Peru S.A.C.    Peru
Blue Fuels Group LP   Texas
Clean Energy Texas LNG, LLC   Texas
DFW Airport CNG Fueling Partnership, LLP   Texas
TranStar Energy Company LP   Texas
CERF Bristol, LLC   Virginia
IMW Industries, Inc.    Washington
M&S Rentals, LLC   Wyoming
Natural/Peoples LLC*   Wyoming
Natural/Total LLC*   Wyoming
ServoTech Engineering, Inc.   Michigan
Southstar LLC   Wyoming
Wyoming Northstar Incorporated   Wyoming
*
Own less than 100%



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CLEAN ENERGY FUELS CORP. SUBSIDIARIES as of December 31, 2012
 EX-23.1 9 a2213180zex-23_1.htm EX 23.1
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Exhibit 23.1


Consent of Independent Registered Public Accounting Firm

The Board of Directors
Clean Energy Fuels Corp.:

        We consent to the incorporation by reference in the registration statements (Nos. 333-152306, 333-168433, 333-145434, 333-150331, 333-156776, 333-159799, 333-164301, 333-171957, 333-174989, 333-178877, 333-177043, 333-179223 and 333-186705) on Form S-3 and Form S-8 of Clean Energy Fuels Corp. and subsidiaries of our report dated February 28, 2013, with respect to the consolidated balance sheets of Clean Energy Fuels Corp. and subsidiaries as of December 31, 2011 and 2012, and the related consolidated statements of operations, stockholders' equity and comprehensive income (loss), and cash flows for each of the years in the three-year period ended December 31, 2012, and the related financial statement schedule and the effectiveness of internal control over financial reporting as of December 31, 2012, which reports appear in the December 31, 2012 annual report on Form 10-K of Clean Energy Fuels Corp. and subsidiaries.

/s/ KPMG LLP

Los Angeles, California
February 28, 2013



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Consent of Independent Registered Public Accounting Firm
 EX-31.1 10 a2213180zex-31_1.htm EX 31.1
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Exhibit 31.1


Certifications

I, Andrew J. Littlefair, certify that:

1.
I have reviewed this Form 10-K for the fiscal year ended December 31, 2012 of Clean Energy Fuels Corp.;

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

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

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

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

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

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

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

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

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

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

Date: February 28, 2013

/s/ ANDREW J. LITTLEFAIR
 Andrew J. Littlefair
 President and Chief Executive Officer
(Principal Executive Officer)
    



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Certifications
 EX-31.2 11 a2213180zex-31_2.htm EX 31.2
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Exhibit 31.2


Certifications

I, Richard R. Wheeler, certify that:

1.
I have reviewed this Form 10-K for the fiscal year ended December 31, 2012 of Clean Energy Fuels Corp.;

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

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

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

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

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

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

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

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

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

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

Date: February 28, 2013

/s/ RICHARD R. WHEELER
 Richard R. Wheeler
 Chief Financial Officer
(Principal Financial Officer)
    



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Certifications
 EX-32.1 12 a2213180zex-32_1.htm EX 32.1
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Exhibit 32.1


CERTIFICATION REQUIRED BY
SECTION 1350 OF TITLE 18 OF THE UNITED STATES CODE

        Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, each of the undersigned hereby certifies in his capacity as the specified officer of Clean Energy Fuels Corp. (the Company), that, to the best of his knowledge, the Annual Report of the Company on Form 10-K for the fiscal year ended December 31, 2012 fully complies with the requirements of Section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934, and that the information contained in such report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the financial statements included in such report.

Date: February 28, 2013    

/s/ ANDREW J. LITTLEFAIR
 Andrew J. Littlefair
 President and Chief Executive Officer
(Principal Executive Officer)
 
 

 

Date: February 28, 2013    

/s/ RICHARD R. WHEELER
 Richard R. Wheeler
 Chief Financial Officer
(Principal Financial Officer)
 
 

        This certification accompanies this Report on Form 10-K pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and shall not be deemed filed by the Company for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the "Exchange Act"). Such certification will not be deemed to be incorporated by reference into any filing under the Securities Act of 1933, as amended, or the Exchange Act, except to the extent that the Company specifically incorporates it by reference.



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CERTIFICATION REQUIRED BY SECTION 1350 OF TITLE 18 OF THE UNITED STATES CODE
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Derivative by Contract Period [Domain] The period that identifies a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. Derivative October to December 2012 [Member] October to December, 2012 Represents information pertaining to derivative instruments for which the contract period is from October to December 2012. Entity [Domain] Derivative, Nonmonetary Notional Amount Gallons Derivative July to December, 2012 [Member] July to December, 2012 Represents the information pertaining to derivative instruments for which the contract period is from July to December 2012. Derivative January to May, 2013 [Member] January to May, 2013 Represents the information pertaining to derivative instruments for which the contract period is from January to May 2013. Derivative January to December, 2013 [Member] 2013 Represents information pertaining to derivative instruments for which the contract period is from January to December 2013. Derivative January to May 2014 [Member] January to May, 2014 Represents information pertaining to derivative instruments for which the contract period is from January to May 2014. Derivative Other Disclosures [Abstract] Notional amounts and weighted-average fixed prices per gasoline gallon equivalent of derivative instruments Series I warrants Warrants Fair Value Disclosure Fair value, as of the balance sheet date, of warrants. A warrant is a security that gives the holder the right to purchase shares of common stock in accordance with the terms of the instrument, usually upon payment of a specified amount. Income Tax Examination Claims Disallowed The amount of claims disallowed under the income tax examination. Claims disallowed under Volumetric Excise Tax Credit program by IRS Miscellaneous Other Receivables [Member] Represents the information pertaining to miscellaneous other receivables. Other IMW Future Payment Notes [Member] Represents the information pertaining to notes issued to IMW in connection with acquisition. IMW Notes IMW Notes Chesapeake Notes [Member] CHK Notes Represents information pertaining to the Chesapeake Notes issued to Chesapeake NG Ventures Corporation (Chesapeake), an indirect wholly-owned subsidiary of Chesapeake Energy Corporation. CHK Note Baytree Investments Mauritius Pte Ltd [Member] Baytree Investments (Mauritius) Pte Ltd Represents the information pertaining to Baytree Investments (Mauritius) Pte Ltd. Debt Instrument, Principal Amount Transferred Principal amount transferred Represents the principal amount of notes transferred. Represents the information pertaining to notes issued in connection with acquisition of entity's membership interests in Dallas Clean Energy, LLC ("DCE"). DCE Notes [Member] DCEMB notes DCE Loan Schedule of assumptions used in estimating fair value of each RSU on the date of grant using the Monte Carlo Method Tabular disclosure of the significant assumptions used during the year to estimate the fair value of performance-based restricted stock units, including, but not limited to: (a) expected term, (b) expected volatility of the entity's shares, (c) expected dividends, (d) risk-free rate(s), and (e) discount for post-vesting restrictions. Schedule of Share Based Payment Award, Performance Based RSU Valuation Assumptions [Table Text Block] Share Based Compensation Arrangement by Share Based Payment Award, Number of Shares of Common Stock Entitled Per Unit of Award Held Number of shares of common stock to be received for each performance unit Represents the number of shares of common stock the holder is entitled to receive for each award unit held. Gross Unrealized Gains Available-for-sale Securities, Gross Unrealized Gains Share Based Compensation Arrangement by Share Based Payment Award, Period from Date of Grant in which Closing Common Stock Price Must Equal or Exceed Closing Price on Award Grant Date Period from the date of grant in which the closing price of the entity's common stock must exceed the closing price in order for a holder to receive one share of common stock for each award Represents the period from the date of grant in which the closing price of the entity's common stock must exceed the closing price on the grant date in order for a holder to receive one share of common stock for each award. Share Based Compensation Arrangement by Share Based Payment Award, Period from Date of Grant after which Award will be Automatically Forfeited Period from the date of grant after which awards will be automatically forfeited if the Stock Price Condition is not satisfied Represents the period from the date of grant after which awards will be automatically forfeited if the closing price of the entity's common stock does not exceed the closing price on the grant date during specified period. Share Based Compensation Arrangement by Share Based Payment Award, Number of Consecutive Trading Days When Closing Common Stock Price Must Equal or Exceed Closing Price on Award Grant Date Number of consecutive trading days during which the closing price of the entity's common stock must exceed the closing price on the grant date in order for a holder to receive one share of common stock for each award Represents the number of consecutive trading days during which the closing price of the entity's common stock must exceed the closing price on the grant date in order for a holder to receive one share of common stock for each award. Share Based Compensation Arrangement by Share Based Payment Award Common Stock Closing Price as Percentage of Closing Price on Award Grant Date Percentage of the closing price of the entity's common stock that the closing price must equal or exceed in order for an award holder to receive one share of common stock for each award Represents the percentage of the closing price of the entity's common stock for twenty consecutive trading days that the closing sales price of the entity's common stock must equal or exceed in order for the holder to receive one share of common stock for each award. Share Based Compensation Arrangement by Share Based Payment Award Equity Instruments Other than Options Weighted Average Remaining Contractual Term [Abstract] Weighted Average Remaining Contractual Term The aggregate amortized cost of investments which are intended to be sold in the short-term (usually less than one year or the normal operating cycle, whichever is longer) including trading securities, available-for-sale securities, held-to-maturity securities, and other short-term investments not otherwise listed in the existing taxonomy. Short Term Investments at Amortized Cost Total short-term investments at amortized cost Fair Value Inputs Assets and Liabilities Quantitative Information [Table] Schedule of inputs used in the fair value measurement of assets and liabilities. This disclosure may include, but is not limited to, the fair value of the asset and liability, valuation technique used to measure fair value, the inputs used to measure fair value, the ranges of the inputs, and the weighted averages of the inputs. Discounted Cash Flow Valuation Technique [Member] DCF Discounted cash flow (DCF) valuation technique used to measure fair value. Black-Scholes Model Black-Scholes Model valuation technique used to measure fair value. Black Scholes Model [Member] Represents the simple average of a range of values. Simple average Simple Average [Member] Fair Value Inputs Assets and Liabilities Quantitative Information [Line Items] Valuation processes for Level 3 Fair Value Measurements Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. Fair Value Inputs Gross Profit Projection Gross profit projection Represents the gross profit projection, used as an input to measure fair value. Fair Value Inputs Probability of Reaching Target Gross Profit Probability of reaching target gross profit (as a percent) Represents the percentage of likelihood of reaching target gross profit, used as an input to measure fair value. Fair Value Inputs Volatility of Gross Profit Rate Volatility of gross profit (peer group) (as a percent) Represents the volatility of the gross profit rate of a peer group, used as an input to measure the fair value. Schedule of Debt Instruments [Table] A table providing information pertaining to short-term and long-term debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. Dallas Clean Energy McCommas Bluff, LLC Represents the information pertaining to Dallas Clean Energy McCommas Bluff, LLC, a Delaware limited liability company (DCEMB), a subsidiary owned by the entity. Dallas Clean Energy Mc Commas Bluff LLC [Member] Facility A Loan Represents the information pertaining to loan taken to finance the acquisition of entity's membership interests in Dallas Clean Energy, LLC (DCE). Facility A Loan [Member] Facility B Loan Represents the information pertaining to loan taken to finance capital improvements of processing facility and to pay certain costs and expenses related to the acquisition of membership interests in Dallas Clean Energy, LLC (DCE). Facility B Loan [Member] A Line of Credit Represents the information pertaining to A line of credit facility entered in connection with acquisition of acquisition of membership interests in Dallas Clean Energy, LLC (DCE). A Line of Credit [Member] DCEMB Revenue Bonds (non recourse to the Company) DCEMB Revenue Bonds Represents the information pertaining to revenue bonds issued by the Dallas Clean Energy McCommas Bluff, LLC, a Delaware limited liability company (DCEMB). DCEMB Revenue Bonds [Member] DCEMB bonds Northstar future payments Represents the information pertaining to debt payment required to be paid in future to Northstar in connection with acquisition. Northstar Future Payments [Member] Represents the information pertaining to notes issued to Weaver Electric, Inc. in connection with acquisition. Weaver Notes [Member] Weaver Notes Dallas Clean Energy, LLC ("DCE") Represents the information pertaining to Dallas Clean Energy, LLC, (DCE), a subsidiary owned by the entity. Dallas Clean Energy LLC [Member] DCE Operating Line of Credit [Member] IMW assumed operating line of credit Represents information pertaining to an operating line of credit facility for IMW. Bank Guarantee Line of Credit [Member] IMW bank guarantee line Represents information pertaining to line of credit facility which allows IMW to provide guarantees and/or standby letters of credit. Forward Exchange Contract Line of Credit [Member] IMW forward exchange contract line Represents information pertaining to a forward exchange contract line for IMW. Master Card Limit [Member] IMW MasterCard Represents information pertaining to MasterCard limit facility for IMW. Renminbi Line of Credit [Member] IMW Renminbi line of credit Represents information pertaining to Renminbi line of credit facility. Renminbi Operating Line of Credit [Member] IMW Renminbi operating line of credit Represents information pertaining to Renminbi operating line of credit facility. Renminbi Sub Limit Line of Credit [Member] IMW Renminbi sub-limit line of credit Represents information pertaining to Renminbi sub-limit line of credit facility entered by IMW. Bengali Taka Operating Line of Credit [Member] IMW Bengali Taka operating line of credit Represents information pertaining to Bengali Taka operating line of credit facility entered by IMW. Entity Well-known Seasoned Issuer Columbian Peso Operating Line of Credit [Member] IMW Columbian Peso operating line of credit Represents information pertaining to Columbian Peso operating line of credit facility entered by IMW. Entity Voluntary Filers SLG Notes [Member] SLG Notes Represents 7.5% convertible notes due 2016. Entity Current Reporting Status IMW Lines of Credit [Member] IMW Lines of Credit Represents information pertaining to lines of credit assumed in connection with the acquisition of IMW. IMW assumed debt Entity Filer Category Debt Covenants January 1 2012 to March 31 2012 [Member] Period between January 1, 2012 and March 31, 2012. January 1, 2012 through March 31, 2012 Entity Public Float Debt Covenants April 1 2012 to June 30 2012 [Member] Period between April 1, 2012 and June 30, 2012. April 1, 2012 through June 30, 2012 Entity Registrant Name Debt Covenants after July 1 2012 [Member] Period after July 1, 2012. July 1, 2012 and thereafter Entity Central Index Key Debt Covenants after April 1 2012 [Member] Period after April 1, 2012 April 1, 2012 and thereafter Debt Covenants before March 31 2012 [Member] Period before March 31, 2012 Until March 31, 2012 Long-term Debt Schedule of Debt Instruments [Line Items] Option to extend the maturity date from August 14, 2011 The period of time for which the reporting entity has the option to extend the maturity date of a debt agreement. Debt Instrument Maturity Date Length of Extension Period Entity Common Stock, Shares Outstanding Percentage of principal required to be paid as per debt repayment schedule Percentage of the required periodic payment applied to principal. Line of Credit Facility Periodic Payment Principal Percentage Prior annual payment of principal delayed Represents the annual payment for the prior year which was delayed. Line of Credit Facility Prior Year Annual Principal Payment Delayed Receivable Type [Axis] Debt Service Coverage Ratio, number of calendar quarters measured Represents the number of calendar quarters used to measure the debt service coverage ratio. Debt Instrument Covenant Debt Service Coverage Ratio Number of Quarters Measured Required debt service coverage ratio for the most recent four calendar quarters Represents the debt service coverage ratio required to be maintained for the most recent four calendar quarters. Debt Instrument Covenant Debt Service Historic Coverage Ratio Projected debt service coverage ratio for the next four calendar quarters Represents the debt service coverage ratio projected to be maintained for the next four calendar quarters. Debt Instrument Covenant Projected Debt Service Coverage Ratio Debt covenant period considered for cash on hand Represents the period considered for cash on hand required to be maintained under the terms of the financial covenant. Debt Instrument Covenant Period for Cash on Hand Debt covenant value, cash on hand Represents the cash on hand required to be maintained under the terms of the financial covenant. Debt Instrument Covenant Cash on Hand Accrued Liabilities Accounts Payable and Accrued Liabilities Disclosure [Text Block] Debt Covenant Period [Axis] Grouping of periods of time for which debt covenants apply. Debt Covenant Period [Domain] Identification of the periods of time covered by the debt covenants. Debt Instrument Covenant Debt to Tangible Net Worth Ratio Debt covenant, debt to tangible net worth ratio Represents the debt to tangible net worth ratio required under the financial covenants. Debt covenant, tangible net worth Represents the tangible net worth required to be maintained under the financial covenants. Debt Instrument Covenant Tangible Net Worth Debt Instrument Covenant Current Ratio Debt covenant, current assets to current liabilities ratio Represents the current assets to current liabilities ratio required to be maintained under the terms of the Assumption Agreement's covenants. Debt Instrument Number Number of convertible promissory notes to be issued Represents the number of convertible promissory notes to be issued by the entity. Represents the number of wholly owned subsidiaries through which the entity entered into a financing arrangement. Number of Wholly Owned Subsidiaries through which Entity Entered into Financing Arrangement Number of wholly owned subsidiaries through which the entity entered into a financing arrangement Number of LNG Production Facilities Being Financed Number of LNG production facilities being financed Represents the number of LNG production facilities, the development, construction and operation of which is being financed. L N G Facility Expected Production Capacity LNG production facilities expected production capacity (in gallons per day) Represents expected LNG production capacity for project. Debt Instrument Face Amount Per Instrument Principal amount of each debt instrument to be issued The stated principal amount of each debt instrument at time of issuance. Document Fiscal Year Focus Debt Instrument Conversion Obligation Common Stock Trade Price as Percentage of Conversion Price Percentage of the trade price of the entity's common stock that the conversion price must be at premium in order for the notes to be convertible (as a percent) Represents the percentage of the trade price of the entity's common stock for at least 20 days within any 30 consecutive trading days that the trade price of the entity's common stock must be at premium of the conversion price in order for the debt instruments to be convertible. Document Fiscal Period Focus Debt Instrument Conversion Obligation Number of Consecutive Trading Days Number of consecutive trading days used to determine the conversion obligation on the notes Represents the number of consecutive trading days in which the daily settlement amounts are totaled to determine the conversion obligation on the debt instrument. Project Completion Period after Initial Funding of Loans Project completion period after the funding of the initial loans Represents the project completion period after the funding of the initial loans. Amortization Period Term Loan Amortization period following conversion into term loan Represents the amortization period of the debt following its conversion into a term loan. Number of days within 30 consecutive trading days in which the trade price of the entity's common stock must be at premium of the conversion price for the notes to be convertible Debt Instrument Conversion Obligation Common Stock Trade Price Number of Trading Days Represents the number of trading days within a period of 30 consecutive trading days the trade price of the entity's common stock must be at premium of the applicable conversion price in order for the debt instruments to be convertible. Represents the maturity period of the debt instrument. Debt Instrument Maturity Period Period during which the debt instrument principal balance is required to be paid Debt Instrument Registration Statement Number Number of registration statements required to be filed under Registration Rights Agreement Represents the number of registration statements required to be filed by entity relating to the resale of the entity's common stock issuable upon conversion of the debt instrument with Securities and Exchange Commission under the terms of Registration Rights Agreement. Debt Instrument Participation in Underwritten Offerings Number Number of underwritten offerings in which the entity would be required to participate under Registration Rights Agreement Represents the number of underwritten offerings of the entity's common stock issuable upon conversion of debt instrument in which the entity would be required to participate on the request of Chesapeake under the terms of Registration Rights Agreement. Monthly liquidated damages expressed as a percentage of principal amount of debt instrument under Registration Rights Agreement (as a percent) Represents the liquidated damages expressed as a percentage of principal amount of debt instrument which the entity would be required to be paid monthly if the entity does not meet certain of its obligations under the Registration Rights Agreement. Debt Instrument Monthly Liquidated Damages Percentage Debt Instrument Annual Liquidated Damages Percentage Limit Annual liquidated damages limit expressed as a percentage of aggregate principal amount of debt instrument under Registration Rights Agreement (as a percent) Represents the maximum annual liquidated damages expressed as a percentage of aggregate principal amount of debt instrument which the entity would be required to be paid if the entity does not meet certain of its obligations under the Registration Rights Agreement. Commitment received, limit of debt securities to be purchased Financing Commitment Maximum Amount Represents the maximum amount of financing to be received under the agreement. Annual payment required Debt Instrument, Periodic Payment, Principal by Cash Amount of required periodic payments applied to principal to be made by the entity under debt obligation. Such payment will be by cash to the holder of debt instrument. Annual cash required to be paid on debt instrument Legal Entity [Axis] Represents the remaining percentage of common stock of the acquiree for which the entity has an option to purchase. Business Acquisition Option to Purchase Remaining Interest Percentage Remaining interest for which the entity has an option to purchase (as a percent) Document Type Business Acquisition Amount to be Paid to Purchase Remaining Interest Exercise price Represents the amount to be paid to acquire remaining interest in the acquiree. Represents the period over which the entity may purchase remaining interest in the acquiree. Business Acquisition Period over which Remaining Interest May be Acquired Period during which remaining interest may be acquired Clean Energy Del Peru [Member] Peru JV Represents information pertaining to Clean Energy del Peru, joint venture in Lima, Peru that operates CNG stations. Demand Revolving Line of Credit [Member] Demand revolving line of credit Represents information pertaining to a demand revolving line of credit facility. Accounts Receivable, Net, Current Accounts receivable, net of allowance for doubtful accounts of $712 and $905 as of December 31, 2011 and December 31, 2012, respectively Debt Instrument Variable Rate Base [Domain] Identification of the reference rate that is used to calculate the variable interest rate of the debt instrument. Demand Revolving Bank Guarantee and Standby Letter of Credit [Member] Demand revolving bank guarantee and standby letter of credit line Represents information pertaining to a demand revolving bank guarantee and standby letter of credit line. Debt Instrument Variable Rate Base [Axis] The alternative reference rates that may be used to calculate the variable interest rate of the debt instrument. Debt Instrument HSBC Prime Rate [Member] HSBC's prime rate The HSBC's prime rate used to calculate the variable interest rate of the debt instrument. Debt Instrument HSBCUS Base Rate [Member] HSBC's U.S. base rate The HSBC's U.S. base rate used to calculate the variable interest rate of the debt instrument. Debt Instrument Variable Rate LIBOR [Member] LIBOR The London Interbank Offered Rate used to calculate the variable interest rate of the debt instrument. Servo Tech Future Payments [Member] ServoTech future payment Represents information pertaining to the debt payment required to be paid in future to ServoTech in connection with the acquisition. Weighted Average Number of Share Outstanding Basic and Diluted [Abstract] Basic and diluted: This element represent that Capital lease receivables. Capital Lease Receivables Capital lease receivables Business Acquisition, Purchase Consideration, Maximum Aggregate Retention Bonus, Payment Maximum aggregate retention bonus required to be paid to key employees, as a part of purchase consideration Represents the maximum amount of annual retention bonus payments required to be made by entity to key employees towards purchase consideration in connection with acquisition. Contingent consideration paid relating to business acquisitions Amount of cash payments that resulted from a contingent consideration arrangement. Business Acquisition, Contingent Consideration, Cash Payment Contingent consideration payment Traded Options Term Term of traded options Represents the term of the traded options. Volumetric Excise Tax Credits [Policy Text Block] Volumetric Excise Tax Credits (VETC) Describes the entity's accounting policy related to Volumetric Excise Tax Credits (VETC). LNG Transportation Costs [Policy Text Block] LNG Transportation Costs Describes the entity's accounting policy related to LNG transportation costs. Acquired Contracts [Member] Acquired contracts Represents details pertaining to the contracts acquired by the entity. Trademark and tradenames Trademarks represent the rights acquired through registration of a trademark to gain or protect exclusive use of a business name, symbol or other device or style and tradenames represent rights acquired through registration of a business name to gain or protect exclusive use thereof. Trademarks and Tradenames [Member] Volumetric Excise Tax Credit [Abstract] Volumetric Excise Tax Credits (VETC) IMW Industries Ltd [Member] IMW I.M.W. Industries Ltd. (IMW), a company that manufactures and services advanced, non-lubricated natural gas fueling compressors and related equipment. Promissory Notes Due in 2012 [Member] Promissory notes due and paid in 2012 Represents promissory notes due and payable in 2012. Promissory Notes Due 07 February 2013 [Member] Promissory notes due and paid on February 7, 2013 Represents promissory notes due and payable on February 07, 2013. Represents the maximum percentage of foreign trade receivables covered by the accounts receivable insurance. Maximum Percentage of Foreign Trade Receivables Covered by Accounts Receivable Insurance Maximum percentage of foreign trade receivables covered by accounts receivable insurance Derivative January to December 2014 [Member] 2014 Represents information pertaining to derivative instruments for which the contract period is from January to December 2014. Income before Income Taxes Excluding Portion Attributable to Noncontrolling Interests Income (loss) before income taxes, total Represents income or loss from continuing operations before income taxes, excluding the portion attributable to noncontrolling interest. Refund of alternative minimum taxes Represents the portion of the difference between total income tax expense or benefit as reported in the income statement and the expected income tax expense or benefit computed by applying the domestic federal statutory income tax rates to pretax income from continuing operations attributable to income that is exempt from income tax because of refund of alternative minimum taxes the entity has received in the period. Income Tax Reconciliation Refund of Alternative Minimum Taxes Accounts Payable, Current Accounts payable LNG Sales [Member] LNG sales Represents details pertaining to LNG sales. Accounts, Notes, Loans and Financing Receivable [Line Items] Other Receivables Represents details pertaining to CNG operations. CNG Operations [Member] CNG operations Williams Gas Processing Company [Member] Williams Gas Processing Company Represents information pertaining to Williams Gas Processing Company. Shell Energy [Member] Shell Energy Represents information pertaining to Shell Energy. So Cal Gas Company and San Diego Gas and Electric [Member] SoCal Gas Company and San Diego Gas and Electric Represents information pertaining to SoCal Gas Company and San Diego Gas and Electric. Schedule of Future Minimum Lease Payments Receivable for Capital Leases [Table Text Block] Schedule of future receipts under the leases Tabular disclosure of future minimum lease payments receivables as of the date of the latest balance sheet presented, in aggregate and for each of the five years succeeding fiscal years, with separate deductions from the total for the amount representing executor costs, including any profit thereon, included in the minimum lease payments receivables and for the amount of the imputed interest necessary to reduce the net minimum lease payments receivables to present value. Capital Leases Weighted Average Interest Rate Weighted average interest rate (as a percent) Represents the calculation as of the balance sheet date of the average interest rate weighted of the amount of leased equipments under capital leases. Capital Leases Sales Type Leases Interest Rate Sales-type leases interest rate (as a percent) Represents the interest rate applicable on the amount of equipment leased under the sales-type leases. Less amount representing interest Amount necessary to reduce net minimum lease payment receivables to present value for capital leases. Capital Leases Future Minimum Payments Receivable Interest Included in Receipts Capital Leases Future Minimum Payments Receivable Present Value of Net Minimum Receipts Present value of future minimum lease receipts Represents the present value of minimum lease payment receivables for capital leases. Fair Value Measurement with Unobservable Inputs Reconciliation Recurring Basis Liability Exercises Represents exercises of warrants that have taken place during the period in relation to liabilities measured at fair value and categorized within level 3 of the fair value hierarchy. Exercise of warrants Fair Value Liabilities Other Disclosures [Abstract] Other disclosures Debt Instrument Annual Payments Made Number Number of annual payments made Represents the number of payment terms of the debt instrument. BAF Technologies Inc [Member] Represents the information pertaining to the acquisition of shares of BAF Technologies, Inc. ("BAF"), under a stock purchase agreement. BAF Business Acquisition Purchase Price Allocation Customer Owned Inventory Recorded as Liability Represents the amount of acquisition cost of a business combination allocated to customer-owned inventory recorded as liability. BusinessAcquisitionPurchasePriceAllocationCustomerOwnedInventoryRecordedAsLiability Customer-owned inventory recorded as an liability Basic and diluted (in dollars per share) Business Acquisitions Pro Forma Earning Per Share Basic and Diluted Represents the pro forma basic and diluted net income per share for a period as if the business combination or combinations had been completed at the beginning of a period. For contingent consideration arrangements recognized in connection with a business combination, this element represents the percentage of aquiree's future gross profit as basis for determining the amount payable. Percentage of acquiree's gross profits as basis for additional contingent consideration Business Combination Contingent Consideration Arrangements Basis Acquiree Gross Profits Percentage Business Combination Contingent Consideration Arrangements Basis for Amount Acquiree Gross Profit Maximum For contingent consideration arrangements recognized in connection with a business combination, this element represents the amount of aquiree's future gross profit as basis for determining the maximum amount payable. Acquiree's future gross profits as basis for maximum aggregate contingent consideration For contingent consideration arrangements recognized in connection with a business combination, this element represents the period of the basis for determining the amount of the payment recorded. Period of acquiree's future gross profits as basis for additional contingent consideration Business Combination Contingent Consideration Arrangements Basis for Amount Period IMW Compressors (Shanghai) Co. Ltd IMW Compressors Shanghai Co Ltd [Member] Represents the information pertaining to the acquisition of IMW Compressors (Shanghai) Co. Ltd. Promissory Notes Due 31 January 2011 [Member] Represents promissory notes due and payable on January 31, 2011. Promissory notes due and paid on January 31, 2011 Promissory Notes Due 31 January 2012 [Member] Represents promissory notes due and payable on January 31, 2012. Promissory notes due and payable on January 31, 2012 Promissory Notes Due 31 January 2013 [Member] Represents promissory notes due and payable on January 31, 2013. Promissory notes due and payable on January 31, 2013 Promissory Notes Due 31 January 2014 [Member] Represents promissory notes due and payable on January 31, 2014. Promissory notes due and payable on January 31, 2014 Represents the number of classes of capital stock authorized by the entity's certificate of incorporation. Capital Stock Number of Authorized Classes Authorized number of classes of capital stock Shares Authorized Authorized shares The maximum number of shares permitted to be issued by an entity's charter and bylaws. Common Stock Voting Rights Per Share Number of votes per share held by holders of common stock Represents the number of voting rights per common share held. Key Executive [Member] Key executives Represents key executives of the entity. Series I Warrant [Member] Series I Warrant Represents information pertaining to Series I warrant. GE Credit Agreement [Member] GE Credit Agreement Represents the financing arrangement entered by entity with General Electric. Tranche A Loan [Member] Tranche A Loans Represents information pertaining to Tranche A Loans under the GE credit agreement. Tranche B Loan [Member] Tranche B Loans Represents information pertaining to Tranche B Loans under the GE credit agreement. GE Warrant [Member] GE Warrant Represents information pertaining to the warrant issued to General Electric. Series II Warrant [Member] Series II Warrant Represents information pertaining to Series II warrant. Series I Warrant Amended [Member] Amended Series I Warrant Represents information pertaining to amended Series I warrant. Number of Shares of Common Stock in Unit Number of shares of the company's common stock in a unit Represents the number of shares of the company's common stock in each unit. Unit Price Unit price (in dollars per unit) Price of a single unit of a number of saleable units offered by the company. Class of Warrant or Rights Period from which Warrants or Rights Exercisable Period from which warrants are exercisable Represents the period from which warrants are exercisable. Class of Warrant or Rights Expiration Term Expiration term The period of time, from the date warrants became exercisable until the time at which they expire. Class of Warrant or Rights Number of Holders of Warrant Entering into Amendment Number of holders of warrants entering into amendment with the company Represents the number of holders of warrants entering into an amendment with the entity. Class of Warrant or Right Gain on Exercise of Warrants Gain on exercise of warrants Represents the gain on exercise of warrants. Stock Option Plan 2002 [Member] 2002 Plan Represents the 2002 Stock Option Plan (the 2002 Plan) of the entity. Equity Incentive Plan 2006[Member] 2006 Plan Represents the 2006 Equity Incentive Plan (the 2006 Plan) of the entity. Share Based Compensation Arrangements by Share Based Payment Award Options Expiration Term Expiration term The period of time, from the grant date until the time at which the share-based option award expires. Share Based Compensation Arrangement by Share Based Payment Award for Options Granted to 10 Percent Shareholder Purchase Price of Common Stock Percent Purchase price of options granted to 10% stockholders expressed as percentage of fair market value of common stock Represents the purchase price of options granted to 10 percent stockholders expressed as a percentage of the fair market value of the entity's common stock on the grant date. Share Based Compensation Arrangement by Share Based Payment Award Options Percentage of Shareholders 110 Percent FV Percentage ownership of stock for which the option purchase price will be 110% of fair market Represents the ownership percentage of stock to whom the purchase price of an option is not less than 110 percent of the fair market value on the grant date. Weighted Average Remaining Contractual Term Share Based Compensation Arrangement by Share Based Payment Award Options Weighted Average Remaining Contractual Term [Abstract] Share Based Compensation Arrangement by Share Based Payment Award Aggregate Intrinsic Value [Abstract] Aggregate Intrinsic Value Stock Issued During Period, Shares Exercise of Overallotment Option Represents the number of shares issued to underwriter upon exercise of its overallotment option. Number of shares issued to underwriter upon exercise of options Units Authorized Represents the number of units authorized under a placement agreement. Number of units authorized under the Placement Agent Agreement Number of shares of common stock issued during the period for units under a placement agreement. Number of shares issued for units under Placement Agent Agreement Stock Issued During Period, Shares for Units Class of Warrant or Right Number of Warrants Immediately Exercisable Number of shares immediately exercisable Represents the number of shares that are immediately exercisable under the warrant. Class of Warrant or Right Additional Number of Warrants Become Exercisable when Specified Loan will be Made under Credit Agreement Number of shares that will become exercisable at the time the specified loan is made under the credit agreement Represents the number of warrants that will become exercisable at the time that specified loan is made under the credit agreement. Class of Warrant or Right Additional Number of Warrants Become Exercisable when Specified Principal Amount of Specified Loan will be Made under Credit Agreement Number of additional shares that will become exercisable at the time that specified loan of at least $15,000,000 principal amount is made under the credit agreement Represents the number of additional shares that will become exercisable at the time that specified loan in specified aggregate principal amount is made under the credit agreement. Class of Warrant or Right Additional Number of Warrants Become Exercisable Based on Minimum Specified Principle Amount Made under Specified Loan Minimum specified principal amount for additional shares to become exercisable Represents the minimum specified principal amount of specified loan under the credit agreement, at which additional shares become exercisable. Class of Warrant or Right Additional Number of Warrants Become Exercisable if No Loans are Made Additional number of shares that will be exercisable if no loans are made Represents the additional number of shares that will be exercisable under the warrant if no loans are made. Warrant Dilution Protection Trigger Percentage of Market Price for Sale of Stock Percentage of market price below which stock sale is a "Dilutive Issuance" Represents the trigger percentage of the market price the the entity's stock can be issued, below which the warrant holder is entitled to a dilution adjustment. Proceeds from Issuance of Units Represents the proceeds received after deducting the placement agent's fees and other offering expenses related to the sale of units. Proceeds after deducting the placement agent's fees and other offering expenses related to the sale of units Represents the amount paid to warrant holder on modification of the term of the warrant. Amount paid to holders on modification of term Class of Warrant or Rights, Amount Paid on Modification of Term Total number of warrants exercised (in shares) Stock Issued During Period, Shares Warrants Exercised Number of shares issued during the period due to warrants exercised. Stock Issued During Period, Value, Warrants Exercised Value of stock issued as a result of the exercise of warrants. Total value of warrants exercised Federal and State [Member] Federal and state Represents the tax departments of the federal and state governments entitled to levy and collect income taxes from the entity. Class of Warrant or Right Number of Securities Called by Each Warrant or Right Number of shares that can be purchased upon exercise of each warrant Number of securities into which each warrant or right may be converted. Number of shares that can be purchased upon exercise of warrant Fuel Tax Credits [Member] Represents information pertaining to the amount of fuel tax credits receivable by the entity. Fuel tax credits Unrecorded Unconditional Purchase Obligation Balance Years One to Four Amount of the fixed and determinable portion of the unrecorded unconditional purchase obligation maturing from the next four fiscal years. 2013 through 2016 Number of capital lease assets leased to customers Capital Leased Assets Number of Units Leased to Customer Represents number of capital lease assets leased to customers at specified rate of interest. Antidilutive Securities included in Computation of Earnings Per Share Amount Common stock related to the GE Warrant included in the basic and dilutive net loss per share calculation Represents the securities (including those issuable pursuant to contingent stock agreements) that could potentially dilute basic earnings per share or earnings per unit in the future that were included in the computation of diluted EPS or EPU for the period presented. Payments for Loans Customers Loans made to customers The cash outflow resulting from loans made to customers. Business Acquisition Amount Paid to Purchase Remaining Interest Percentage Percentage of amount to be paid to purchase remaining interest Represents the percentage of amount to be paid to purchase remaining interest under the business acquisition. Debt Instrument Periodic Payment Common Share Issue Common stock issued on debt instrument Represents the amount of periodic payments made by the issue of common shares applied to the principal under the debt obligation. Payment as Percentage of Budgeted Cost of Projects Percentage of the budgeted costs of the Projects which the Company agreed to pay Represent the percentage of the budgeted costs of the LNG projects which the entity agreed to pay. Accrued Professional Fees, Current Accrued professional fees Accrued Salaries, Current Salaries and wages United States UNITED STATES Accrued Employee Benefits, Current Accrued employee benefits Accrued Liabilities, Current Accrued liabilities Total Accumulated Other Comprehensive Income (Loss) Accumulated Other Comprehensive Income (Loss) [Member] Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax Remaining unrecognized loss recorded as a component of accumulated other comprehensive income (loss) Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment Less: accumulated depreciation Accumulated Other Comprehensive Income (Loss), Net of Tax Accumulated other comprehensive loss Acquired Indefinite-lived Intangible Asset, Amount Purchase price allocated to trademarks, which the management believes to have an indefinite useful life Acquired Finite-lived Intangible Asset, Amount Purchase price allocated to the identifiable intangible assets related to non-compete agreements, customer relationships, and backlog Purchase price allocated to the identifiable intangible assets Additional Paid in Capital, Common Stock Additional paid-in capital Additional Paid-In Capital Additional Paid-in Capital [Member] Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract] Adjustments to reconcile net loss to net cash provided by (used in) operating activities: Adjustments to Additional Paid in Capital, Warrant Issued Issuance of warrants in connection with the GE Credit Agreement Fair value of warrants issued, additional paid-in capital Adjustments to Additional Paid in Capital, Share-based Compensation, Requisite Service Period Recognition Stock-based compensation Advertising expense Advertising Expense Advertising Costs, Policy [Policy Text Block] Advertising Costs Stock-based compensation expense, net of tax Allocated Share-based Compensation Expense, Net of Tax Allocated Share-based Compensation Expense Stock-based compensation expense Allowance for Doubtful Accounts Receivable, Current Accounts receivable, allowance for doubtful accounts (in dollars) Allowance for Doubtful Notes Receivables Allowance for Notes Receivable [Member] Allowances for Doubtful Trade Receivables Allowance for Trade Receivables [Member] Amortization expense Amortization of Intangible Assets Amortization of debt issuance cost Amortization of Financing Costs Accretion of notes payable Amortization of Debt Discount (Premium) Proceeds from grants Amount of Regulatory Assistance Received Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount Anti-dilutive securities ( in shares) Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] Amounts outstanding of anti-dilutive securities Net Loss Per Share Antidilutive Securities, Name [Domain] Antidilutive Securities [Axis] Beginning balance Ending balance Asset Retirement Obligation Asset Retirement Obligations Asset Retirement Obligation [Abstract] Accretion expense Asset Retirement Obligation, Accretion Expense Asset retirement obligation, included in other long-term liabilities Asset Retirement Obligations, Noncurrent Asset Impairment Charges Asset impairments Liabilities incurred Asset Retirement Obligation, Liabilities Incurred Activity of the asset retirement obligation Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] Liabilities settled Asset Retirement Obligation, Liabilities Settled Asset Retirement Obligations, Policy [Policy Text Block] Asset Retirement Obligations Assets, Current [Abstract] Current assets: Assets [Abstract] Assets Assets, Current Total current assets Assets Total assets Assets, Fair Value Disclosure [Abstract] Assets: Automobile Loan [Member] Loans to customers to finance vehicle purchases Available-for-sale Securities, Debt Securities, Current Estimated Fair Value Available-for-sale Securities, Fair Value Disclosure Available-for-sale securities Available-for-sale Debt Securities, Amortized Cost Basis Amortized Cost Available-for-sale Securities, Gross Unrealized Losses Gross Unrealized Losses Business Acquisition [Axis] Business Acquisition, Cost of Acquired Entity, Cash Paid Cash payment Cash paid in connection with acquisition Business Acquisition, Purchase Price Allocation, Current Assets Current assets Amount to be paid to purchase remaining interest Business Acquisition, Cost of Acquired Entity, Liabilities Incurred Pro forma results of operations Business Acquisition, Pro Forma Information [Abstract] Fair value of contingent consideration Business Acquisition, Contingent Consideration, at Fair Value Goodwill Business Acquisition, Purchase Price Allocation, Goodwill Amount Business Acquisition, Percentage of Voting Interests Acquired Interest acquired (as a percent) Ownership interest acquired (as a percent) Revenue Business Acquisition, Pro Forma Revenue Price allocated to tangible assets Business Acquisition, Purchase Price Allocation, Tangible Assets Aggregate contingent consideration payment Business Acquisition, Contingent Consideration, Potential Cash Payment Business Acquisition, Acquiree [Domain] Schedule of Company's unaudited pro forma results of operations as if the acquisition had occurred at on January 1, 2010 Business Acquisition, Pro Forma Information [Table Text Block] Business Acquisition, Purchase Price Allocation, Assets Acquired (Liabilities Assumed), Net Total purchase price Business Acquisition, Purchase Price Allocation [Abstract] Allocation of aggregate purchase price Estimate of fair values of assets acquired and liabilities assumed Business Acquisition, Purchase Price Allocation, Current Assets, Cash and Cash Equivalents Cash acquired Net (loss) Business Acquisition, Pro Forma Net Income (Loss) Liabilities assumed Business Acquisition, Purchase Price Allocation, Liabilities Assumed Acquisitions Customer-owned inventory recorded as an asset Business Acquisition, Purchase Price Allocation, Current Assets, Inventory Business Acquisition, Purchase Price Allocation, Current Liabilities Current liabilities assumed Business Acquisition, Purchase Price Allocation, Intangible Assets Other than Goodwill Identifiable intangible assets Business Acquisition, Purchase Price Allocation, Assets Acquired Total assets acquired Total assets acquired Business Acquisition [Line Items] Acquisitions Liquefied Natural Gas Station Construction Acquisitions Natural Gas Fueling Compressors Amount paid for acquisition Business Acquisition, Cost of Acquired Entity, Purchase Price Business Acquisition, Purchase Price Allocation, Property, Plant and Equipment Property, plant and equipment Revenue Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual Business Combination Disclosure [Text Block] Acquisitions Debt acquired Business Acquisition, Purchase Price Allocation, Noncurrent Liabilities, Long-term Debt Contingent liability Business Acquisition, Purchase Price Allocation, Preacquisition Contingency Accrual Net loss Business Combination, Pro Forma Information, Earnings or Loss of Acquiree since Acquisition Date, Actual Gain on contingent consideration for acquisitions Business Combination, Contingent Consideration Arrangements, Change in Amount of Contingent Consideration, Liability Contingent consideration Business Combination, Contingent Consideration Arrangements [Abstract] Impairment charge related to an investment Cost-method Investments, Other than Temporary Impairment Impairment of cost method investment Investment amount 2014 Capital Leases, Future Minimum Payments Due in Two Years Capital Leases, Future Minimum Payments Due in Five Years 2017 Present value of future minimum lease payments Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments Total minimum lease payments Capital Leases, Future Minimum Payments Due Accumulated amortization Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation Value of the equipment under capital lease Capital Leased Assets, Gross 2017 Capital Leases, Future Minimum Payments, Receivable in Five Years 2013 Capital Leases, Future Minimum Payments Receivable, Next Twelve Months 2015 Capital Leases, Future Minimum Payments Due in Three Years 2013 Capital Leases, Future Minimum Payments Due, Next Twelve Months Future receipts under the leases Capital Leases, Future Minimum Payments Receivable, Fiscal Year Maturity [Abstract] Capital Leases, Future Minimum Payments Due Thereafter Thereafter Capital Expenditures Incurred but Not yet Paid Amount included in accounts payable balances 2015 Capital Leases, Future Minimum Payments, Receivable in Three Years Future payments under these capital leases Capital Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract] 2014 Capital Leases, Future Minimum Payments, Receivable in Two Years Total Capital Leases, Future Minimum Payments Receivable Thereafter Capital Leases, Future Minimum Payments, Receivable Due Thereafter Capital Lease Obligations [Member] Capital lease obligations 2016 Capital Leases, Future Minimum Payments, Receivable in Four Years 2016 Capital Leases, Future Minimum Payments Due in Four Years Less current portion Capital Lease Obligations, Current Capital lease obligations, less current portion Capital Lease Obligations, Noncurrent Less amount representing interest Capital Leases, Future Minimum Payments, Interest Included in Payments Capitalized Computer Software, Net Capitalized software costs, net Capitalized Computer Software, Accumulated Amortization Accumulated amortization on the capitalized software costs Capitalized Computer Software, Amortization Amortization expense related to the capitalized software costs Cash and Cash Equivalents Disclosure [Text Block] Cash and Cash Equivalents Cash and Cash Equivalents, at Carrying Value Cash and cash equivalents Cash and cash equivalents, beginning of year Cash and cash equivalents, end of year Cash and Cash Equivalents, Policy [Policy Text Block] Cash and Cash Equivalents Cash and Cash Equivalents Certificates of Deposit, at Carrying Value Certificate of deposits Certificates of Deposit [Member] Certificate of deposits Class of Warrant or Right [Domain] Stockholders' Equity Class of Stock [Line Items] Class of Warrant or Right [Axis] Class of Warrant or Right, Exercise Price of Warrants or Rights Exercise price of the warrant Exercise price (in dollars per share) Class of Stock [Domain] Class of Warrant or Right, Number of Securities Called by Warrants or Rights Number of shares that can be purchased upon exercise of warrants Commitments and Contingencies Commitments Contingencies and Guarantees [Text Block] Commitments and Contingencies Commitments and contingencies Commitments and Contingencies. Common stock Common Stock [Member] Common Stock, Shares, Outstanding Common stock, outstanding shares Common Stock, Value, Issued Common stock, $0.0001 par value. Authorized 149,000,000 shares; issued and outstanding 85,433,258 shares and 87,634,478 shares at December 31, 2011 and December 31, 2012, respectively Common Stock, Shares, Issued Common stock, issued shares Balance (in shares) Balance (in shares) Common Stock, Par or Stated Value Per Share Common stock, par value (in dollars per share) Common stock, Par value (in dollars per share) Common Stock, Shares Authorized Common stock, Authorized shares 401(k) Plan Deferred tax assets: Components of Deferred Tax Assets [Abstract] Components of Deferred Tax Liabilities [Abstract] Deferred tax liabilities: Comprehensive Income (Loss), Net of Tax, Attributable to Parent Comprehensive loss Comprehensive Income (Loss) Comprehensive Income, Policy [Policy Text Block] Comprehensive income (loss) Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest Total Comprehensive Income (Loss) Comprehensive Income [Member] Concentration Risk Type [Domain] Concentration of Credit Risk Concentration Risk [Line Items] Supplier Concentrations Concentration Risk Benchmark [Domain] Concentration Risk [Table] Concentration Risk Benchmark [Axis] Concentration of Credit Risk Concentration Risk, Credit Risk, Policy [Policy Text Block] Concentration Risk Disclosure [Text Block] Supplier Concentrations Concentration Risk Type [Axis] Concentration risk (as a percent) Concentration Risk, Percentage Basis of Presentation Consolidation, Policy [Policy Text Block] Construction in Progress [Member] Construction in progress Convertible Notes Payable [Member] Convertible notes Corporate Debt Securities [Member] Corporate bonds Cost and Equity Method Investments Disclosure [Text Block] Investment in Other Entities Cost of Goods Sold Product cost of sales Investments in other entities Cost Method Investments Natural gas expense Cost of Goods, Product Line [Member] Cost of Services Service cost of sales Cost of Goods and Services Sold [Abstract] Cost of sales: Costs and Expenses [Abstract] Operating expenses: Costs and Expenses Total operating expenses Credit Facility [Domain] Credit Facility [Axis] State Current State and Local Tax Expense (Benefit) Current: Current Income Tax Expense (Benefit), Continuing Operations [Abstract] Total current Current Income Tax Expense (Benefit) Foreign Current Foreign Tax Expense (Benefit) Federal Current Federal Tax Expense (Benefit) Customer relationships Customer Relationships [Member] Debt Instrument, Description of Variable Rate Basis Debt, variable interest rate basis Debt Security [Axis] Amount of principal and accrued interest under debt conversion Debt Conversion, Original Debt, Amount Amount of principal converted into stock Debt and Capital Leases Disclosures [Text Block] Long-term Debt Debt and Capital Lease Obligations Total debt and capital lease obligations Common stock issued upon conversion of debt (in shares) Debt Conversion, Converted Instrument, Shares Issued Long-term Debt Debt Instrument, Convertible, Conversion Price Conversion price of shares (in dollars per share) Debt Instrument, Basis Spread on Variable Rate Percentage of margin added to reference rate to determine interest rate on debt Debt Instrument [Axis] Debt Instrument, Decrease, Repayments Amount paid Debt Instrument, Face Amount Debt issuance amount Annual payment required Debt Instrument, Annual Principal Payment Coupon interest rate (as a percent) Debt Instrument, Interest Rate, Effective Percentage Debt Instrument, Name [Domain] Debt Instrument, Periodic Payment, Principal Annual payment required Annual payment required Debt Securities [Member] Total available-for-sale securities Debt Instrument, Interest Rate, Stated Percentage Coupon interest rate (as a percent) Interest rate (as a percent) Federal Deferred Federal Income Tax Expense (Benefit) Deferred: Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract] Foreign Deferred Foreign Income Tax Expense (Benefit) Total deferred tax liabilities Deferred Tax Liabilities, Gross Total deferred Deferred Income Tax Expense (Benefit) Net deferred tax assets Deferred Tax Assets, Net of Valuation Allowance Derivative loss Deferred Tax Assets, Derivative Instruments Total deferred tax assets Deferred Tax Assets, Gross State Deferred State and Local Income Tax Expense (Benefit) Deferred Revenue, Current Deferred revenue Loss carryforwards Deferred Tax Assets, Operating Loss Carryforwards Other Deferred Tax Assets, Other Accrued expenses Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Accrued Liabilities Alternative minimum tax and general business credits Deferred Tax Assets, Tax Credit Carryforwards Stock option expense Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Share-based Compensation Cost Net deferred tax assets (liabilities) Deferred Tax Liabilities, Net Less valuation allowance Deferred Tax Assets, Valuation Allowance Valuation allowance Maximum percentage of base pay that can be contributed by employees through salary deferrals Defined Contribution Plan, Maximum Annual Contribution Per Employee, Percent Contribution by the company Defined Contribution Plan, Cost Recognized Depreciation, Depletion and Amortization Depreciation and amortization Derivative Liabilities, Current Derivative liability Short-term liability related to derivative instruments included in accrued liabilities Derivative Liability, Fair Value, Gross Asset Derivative asset recorded in prepaid expenses and other current assets Derivative [Line Items] Derivative Transactions Derivative Instruments and Hedging Activities Disclosure [Text Block] Derivative Transactions Derivative, Nonmonetary Notional Amount, Price Per Gallon Price Per Gasoline Gallon Equivalent Derivative Financial Instruments, Liabilities, Fair Value Disclosure Natural gas futures contracts Derivative Liabilities Derivative liability Derivative [Table] Derivative Transactions Derivative Liabilities, Noncurrent Long-term liability related to derivative instruments included in other long-term liabilities Derivative, Gain (Loss) on Derivative, Net Derivative gain Derivative Liability, Fair Value, Gross Liability Derivative liability recorded in accrued liabilities Derivative, by Nature [Axis] Derivative, Gain (Loss) on Derivative, Net [Abstract] Derivative gains: Derivative, Name [Domain] Derivative Instruments, Gain (Loss) Recognized in Income, Net Loss on derivative instrument recognized in cost of sales Derivatives, Policy [Policy Text Block] Derivative Financial Instruments Description of New Accounting Pronouncements Not yet Adopted [Text Block] Recently Adopted Accounting Changes and Recently Issued Accounting Standards Boone Pickens Director [Member] Disclosure of Compensation Related Costs, Share-based Payments [Text Block] Stock-Based Compensation Stock-Based Compensation Earnings Per Share, Diluted Diluted (in dollars per share) Earnings Per Share, Basic Basic (in dollars per share) Earnings Per Share [Text Block] Earnings Per Share Earnings Per Share, Policy [Policy Text Block] Net Loss Per Share Earnings Per Share Loss per share: Effect of exchange rates on cash and cash equivalents Effect of Exchange Rate on Cash and Cash Equivalents, Continuing Operations Reconciliation of the income tax provision Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Abstract] Federal income tax rate (as a percent) Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition Weighted average period over which the total unrecognized compensation cost related to non-vested units is expected to be recognized Total unrecognized compensation cost related to non-vested shares Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Stock Options Total unrecognized compensation cost related to non-vested shares Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Share-based Awards Other than Options Total unrecognized compensation cost related to non-vested units Employee Service Share-based Compensation, Aggregate Disclosures [Abstract] Summary of stock-based compensation expense Equity Method Investments Investment amount Equity Method Investment, Ownership Percentage Ownership interest (as a percent) Proceeds from Equity Method Investment, Dividends or Distributions Dividend distribution Common stock price per share (in dollars per share) Equity Issuance, Per Share Amount Equity Component [Domain] Equity Method Investee, Name [Domain] Equity Method Investment, Net Sales Proceeds Ownership interest sold Measurement Frequency [Axis] Fair Value Assumptions, Expected Volatility Rate Implied volatility of the Company's common stock (as a percent) Fair Value, Hierarchy [Axis] Liability Class [Axis] Discount rate (as a percent) Fair Value Inputs, Discount Rate Fair Value, Measurements, Recurring [Member] Fair value measured on recurring basis Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value Balance beginning of year Ending Balance Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements Payments Fair Value, Measurement Frequency [Domain] Fair Value Measurements, Recurring and Nonrecurring [Table] Fair Value by Liability Class [Domain] Fair Value Inputs [Abstract] Unobservable Input Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Purchases Business combinations Fair Value, Measurements, Fair Value Hierarchy [Domain] Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Issues Issuance of warrants Schedule of fair value measurements of liabilities which fall within level 3 of the fair value hierarchy Fair Value Inputs, Liabilities, Quantitative Information [Table Text Block] Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Fair Value Measurements Fair Value Assumptions, Expected Dividend Rate Dividend yield (as a percent) Fair Value Measurements Fair Value Disclosures [Text Block] Fair Value Measurements Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block] Reconciliation of the beginning and ending balances of items measured at fair value on a recurring basis that used significant unobservable inputs (Level 3) Fair Value, Assets Measured on Recurring Basis [Table Text Block] Schedule of information by level for assets and liabilities that are measured at fair value on a recurring basis Fair Value of Financial Instruments, Policy [Policy Text Block] Fair Value of Financial Instruments Fair Value, Inputs, Level 3 [Member] Level 3 Level 1 Fair Value, Inputs, Level 1 [Member] Fair Value, Inputs, Level 2 [Member] Level 2 Total (gain) loss included in earnings Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] Reconciliation of the beginning and ending balances of items measured at fair value using significant unobservable inputs (Level 3) Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Transfers, Net Transfers In/Out Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] Fair Value Measurements Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Table] Capital lease receivables Financing Receivable [Member] Finite-Lived Intangible Asset, Useful Life Identifiable intangible assets, estimated useful lives Estimated useful lives Finite-Lived Intangible Assets, Major Class Name [Domain] 2017 Finite-Lived Intangible Assets, Amortization Expense, Year Five Total intangible assets Finite-Lived Intangible Assets, Gross Goodwill and intangible assets Finite-Lived Intangible Assets [Line Items] 2015 Finite-Lived Intangible Assets, Amortization Expense, Year Three Estimated amortization expense Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract] Finite-Lived Intangible Assets by Major Class [Axis] Less accumulated amortization Finite-Lived Intangible Assets, Accumulated Amortization 2013 Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months 2016 Finite-Lived Intangible Assets, Amortization Expense, Year Four 2014 Finite-Lived Intangible Assets, Amortization Expense, Year Two Finite-Lived Intangible Assets, Translation Adjustments Foreign currency rate change Foreign Foreign Tax Authority [Member] Foreign exchange transactions gains (losses) Foreign Currency Transaction Gain (Loss), Realized Foreign Currency Transactions and Translations Policy [Policy Text Block] Foreign Currency Translation Foreign Currency Translation Foreign Currency Transaction [Abstract] Future [Member] Natural gas futures contracts Gain (Loss) on Disposition of Assets Loss on disposal of assets Gas Gathering and Processing Equipment [Member] Station equipment Gas Transmission Equipment [Member] LNG trailers Goodwill Goodwill Goodwill and Intangible Assets, Policy [Policy Text Block] Goodwill and Intangible Assets Long-Lived Assets Impaired Long-Lived Assets Held and Used [Line Items] Impairment charge related to an intangible asset Impairment of Intangible Assets (Excluding Goodwill) Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block] Long-Lived Assets Asset impairment charge Impairment of Long-Lived Assets Held-for-use Loss before income taxes Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest Income (loss) before income taxes Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest [Abstract] Foreign Income (Loss) from Continuing Operations before Income Taxes, Foreign Consolidated Statements of Operations Income Tax Disclosure [Text Block] Income Taxes Income Taxes Income Tax Authority [Axis] Income tax examination Income Tax Examination [Line Items] Income Tax Authority [Domain] Income (Loss) from Equity Method Investments Income from equity method investments U.S. Income (Loss) from Continuing Operations before Income Taxes, Domestic Provision (benefit) for income taxes Income Tax Expense (Benefit), Continuing Operations [Abstract] Income Tax Expense (Benefit) Income tax (expense) benefit Income tax expense (benefit) Computed expected tax expense (benefit) Income Tax Reconciliation, Income Tax Expense (Benefit), at Federal Statutory Income Tax Rate Nondeductible expenses Income Tax Reconciliation, Nondeductible Expense Change in valuation allowance Income Tax Reconciliation, Change in Deferred Tax Assets Valuation Allowance Tax rate differential on foreign earnings Income Tax Reconciliation, Foreign Income Tax Rate Differential Possible range of losses associated with disallowed claims Income Tax Examination, Range of Possible Losses Income Tax Examination [Table] State and local taxes, net of federal benefit Income Tax Reconciliation, State and Local Income Taxes Income Taxes Income Tax Uncertainties [Abstract] Additional information on income tax Income Tax, Policy [Policy Text Block] Income Taxes Income Taxes Paid Income taxes paid Tax credits Income Tax Reconciliation, Tax Credits Other Income Tax Reconciliation, Other Adjustments Accrued expenses and other Increase (Decrease) in Accrued Liabilities and Other Operating Liabilities Increase (Decrease) in Deposits Outstanding Return (deposits) on LNG trucks Increase (Decrease) in Accounts Payable Accounts payable Increase (Decrease) in Margin Deposits Outstanding Margin deposits on futures contracts Increase (Decrease) in Operating Capital [Abstract] Changes in operating assets and liabilities, net of assets and liabilities acquired: Increase (Decrease) in Prepaid Expense and Other Assets Prepaid expenses and other assets Increase (Decrease) in Inventories Inventory Increase (Decrease) in Restricted Cash Restricted cash Increase (Decrease) in Receivables Accounts and other receivables Increase (Decrease) in Stockholders' Equity Increase (Decrease) in Stockholders' Equity [Roll Forward] Indefinite-Lived Trademarks Carrying value of trademark of indefinite useful life Intangible Assets, Net (Excluding Goodwill) Intangible assets, net Net intangible assets Interest paid, capitalized Interest Paid, Capitalized Interest expense, net Interest Income (Expense), Nonoperating, Net Interest paid, net of $434, $1,352, and $6,304 capitalized, respectively Interest Paid, Net Internal Revenue Service (IRS) [Member] Federal Inventory, Policy [Policy Text Block] Inventories Inventories Inventory, Net [Abstract] Inventory, Finished Goods, Net of Reserves Finished goods Reserve for Excess and Obsolete Inventory Inventory Valuation Reserve [Member] Inventory, Raw Materials, Net of Reserves Raw materials and spare parts Inventory Disclosure [Text Block] Inventories Inventory, Net Inventory, net Total Inventories Inventory, Work in Process, Net of Reserves Work in process Investment Type Categorization [Domain] Investment Type [Axis] Investment in Other Entities Investments Investments in Debt and Marketable Equity Securities (and Certain Trading Assets) Disclosure [Text Block] Investments Long-term Debt, Type [Domain] Long-term Debt, Type [Axis] Land [Member] Land Lease Agreements [Member] Lease agreements Capitalized Lease Obligation and Receivables Liabilities, Current Total current liabilities Liabilities, Current [Abstract] Current liabilities: Liabilities Total liabilities Liabilities and Equity [Abstract] Liabilities and Stockholders' Equity Liabilities, Fair Value Disclosure [Abstract] Liabilities: Total liabilities and stockholders' equity Liabilities and Equity Line of Credit Facility, Maximum Borrowing Capacity Line of credit limit Debt amount Line of Credit Facility, Unused Capacity, Commitment Fee Percentage Unused facility fee on the unused portion of credit facility (as a percent) Line of Credit Facility, Periodic Payment, Principal Principal amount required to be paid as per debt repayment schedule Loans, Notes, Trade and Other Receivables Disclosure [Text Block] Other Receivables Long-term Debt and Capital Lease Obligations, Current Current portion of long-term debt and capital lease obligations Less amounts due within one year and short-term borrowings Long-term Debt, Fiscal Year Maturity [Abstract] Summary of aggregate maturities of long-term debt Long-term Debt and Capital Lease Obligations Long-term debt and capital lease obligations, less current portion Total long-term debt and capital lease obligations Long-term Investments and Receivables, Net Notes receivable and other long-term assets Long-term Debt, Maturities, Repayments of Principal in Year Three 2015 Long-term Debt, Maturities, Repayments of Principal in Year Two 2014 Long-term Debt, Maturities, Repayments of Principal in Year Four 2016 Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months 2013 Long-term Debt, Maturities, Repayments of Principal in Year Five 2017 Long-term Debt, Maturities, Repayments of Principal after Year Five Thereafter Loss Contingency, Settlement Agreement, Consideration Settlement of dispute against IRS Major Types of Debt Securities [Domain] Marketable Securities [Table Text Block] Summary of Short-term investments Marketing and Advertising Expense [Abstract] Advertising Costs Maximum [Member] Maximum Minimum [Member] Minimum Stockholders' Equity Attributable to Noncontrolling Interest Noncontrolling interest in subsidiary Noncontrolling Interest, Increase from Equity Issuance or Sale of Parent Equity Interest Non-controlling interest contribution Movement in valuation and qualifying accounts Movement in Valuation Allowances and Reserves [Roll Forward] Movement in Standard Product Warranty Accrual [Roll Forward] Changes in the warrant liability Total long-lived assets Long-Lived Assets Cash flows from financing activities: Net Cash Provided by (Used in) Financing Activities, Continuing Operations [Abstract] Net cash used in operating activities Net Cash Provided by (Used in) Operating Activities, Continuing Operations Cash flows from operating activities: Net Cash Provided by (Used in) Operating Activities, Continuing Operations [Abstract] Net increase (decrease) in cash and cash equivalents Net Cash Provided by (Used in) Continuing Operations Net cash used in investing activities Net Cash Provided by (Used in) Investing Activities, Continuing Operations Net Income (Loss) Available to Common Stockholders, Basic Net loss attributable to Clean Energy Fuels Corp. Net loss attributable to Clean Energy Fuels Corp. 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Stockholders' Equity (Tables)
 12 Months Ended
Dec. 31, 2012
Stockholders' Equity  
Summary of compensation expense and related income tax benefit related to the stock-based compensation expense recognized

 

 

 
   Years Ended December 31,  
 
   2010   2011   2012  

Stock-based compensation expense

   $ 11,920   $ 13,473   $ 22,087  
               

Stock-based compensation expense, net of tax

   $ 11,920   $ 13,473   $ 22,087  
               
Summary of Company's stock option activity

 

 

 
   Number of
Shares		   Weighted
Average
Exercise
Price		   Weighted
Average
Remaining
Contractual
Term
(in years)		   Aggregate
Intrinsic
Value		  

Outstanding, December 31, 2011

     10,683,303   $ 10.29              

Options granted

     3,194,000     13.88              

Options exercised

     (1,568,480 )   5.72              

Options forfeited

     (225,146 )   14.18              
                         

Outstanding, December 31, 2012

     12,083,677     11.75     6.54   $ 8,459  
                         

Exercisable, December 31, 2012

     7,981,345     10.65     5.31   $ 14,366  
                         

        
Schedule of weighted-average assumptions used to estimate the fair value of each option on the date of grant using the Black-Scholes option pricing model

The fair value of each option grant is estimated on the date of grant using the Black-Scholes option pricing model with the following assumptions used for grants during the year ended December 31, 2012:

Dividend yield

   0.00%

Expected volatility

   57.6% to 72.8%

Risk-free interest rate

   0.9% to 1.2%

Expected life in years

   6.0
Summary of the company's RSU activity

The following table summarizes the Company's RSU activity during the year ended December 31, 2012:

 
   Number of
Shares		   Weighted Average
Fair Value at
Grant Date		   Weighted
Average
Remaining
Contractual
Term (in years)		  

Outstanding, December 31, 2011

     —     —        

Granted

     1,545,000   $ 11.42        
                   

Outstanding and non-vested, December 31, 2012

     1,545,000   $ 11.42     3.2  
                   
Schedule of assumptions used in estimating fair value of each RSU on the date of grant using the Monte Carlo Method

 

 

 
   January 25,
2012		   May 8,
2012		  

Stock price on date of grant

   $ 15.11   $ 16.71  

Dividend yield

     0.00 %   0.00 %

Expected volatility

     56.51 %   58.49 %

Risk-free interest rate

     0.57 %   0.56 %

Expected life in years

     2.1     2.0  

        

XML 21 R54.htm IDEA: XBRL DOCUMENT v2.4.0.6
Restricted Cash (Details) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2012
Dec. 31, 2011
Restricted Cash    
Short-term restricted cash $ 8,445 $ 4,792
Long term restricted cash 13,208 54,804
Total restricted cash 21,653 59,596
DCEMB bonds
    
Restricted Cash    
Short-term restricted cash 7,776 3,555
Long term restricted cash 952 14,482
CHK Notes
    
Restricted Cash    
Long term restricted cash 12,256 40,322
Standby letters of credit
    
Restricted Cash    
Short-term restricted cash $ 669 $ 1,237
XML 22 R48.htm IDEA: XBRL DOCUMENT v2.4.0.6
Summary of Significant Accounting Policies (Details 4) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Changes in the warrant liability      
Warranty liability at beginning of year $ 3,130 $ 2,338  
Costs accrued for new warranty contracts and changes in estimates for pre-existing warranties 3,733 3,208  
Service obligations honored (4,198) (2,416)  
Warranty liability at end of period 2,665 3,130 2,338
Asset Retirement Obligations      
Asset retirement obligation, included in other long-term liabilities 1,215 964  
Activity of the asset retirement obligation      
Beginning balance 1,179 1,128  
Liabilities incurred 74 8  
Liabilities settled   (3)  
Accretion expense 60 46  
Ending balance 1,313 1,179 1,128
Volumetric Excise Tax Credits (VETC)      
VETC credits recognized as revenue   17,889 16,042
Advertising Costs      
Advertising expense 1,340 1,559 1,260
Foreign Currency Translation      
Foreign exchange transactions gains (losses) $ 678 $ (596) $ 1,902
XML 23 R70.htm IDEA: XBRL DOCUMENT v2.4.0.6
Commitments and Contingencies (Details) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Jul. 15, 2010
Commitments and Contingencies        
Claims disallowed under Volumetric Excise Tax Credit program by IRS       $ 5,073
Settlement of dispute against IRS 2,057      
Fiscal year:        
2013 5,617      
2014 5,445      
2015 5,183      
2016 4,996      
2017 4,702      
Thereafter 11,956      
Total future minimum lease payments 37,899      
Rent expense $ 7,737 $ 6,517 $ 6,190  
XML 24 R55.htm IDEA: XBRL DOCUMENT v2.4.0.6
Investments (Details) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2012
Dec. 31, 2011
Short-term investments    
Gross Unrealized Losses $ (158) $ (126)
Certificate of deposits 10,021 10,000
Total short-term investments at amortized cost 38,333 33,455
Total short-term investments 38,175 33,329
Municipal bonds & notes
    
Short-term investments    
Amortized Cost 23,755 19,703
Gross Unrealized Losses (105) (114)
Estimated Fair Value 23,650 19,589
Zero coupon bonds
    
Short-term investments    
Amortized Cost   712
Estimated Fair Value   712
Corporate bonds
    
Short-term investments    
Amortized Cost 4,557 3,040
Gross Unrealized Losses (53) (12)
Estimated Fair Value 4,504 3,028
Total available-for-sale securities
    
Short-term investments    
Amortized Cost 28,312 23,455
Gross Unrealized Losses (158) (126)
Estimated Fair Value $ 28,154 $ 23,329
XML 25 R78.htm IDEA: XBRL DOCUMENT v2.4.0.6
Fair Value Measurements (Details 2) (USD $)
In Thousands, unless otherwise specified
 3 Months Ended 12 Months Ended 3 Months Ended 12 Months Ended
Dec. 31, 2010
Dec. 31, 2012
Dec. 31, 2012
VPG
Dec. 31, 2010
DCE
Dec. 31, 2010
Operating and Maintenance Contracts
Dec. 31, 2012
Liabilities: Contingent consideration obligations
Dec. 31, 2011
Liabilities: Contingent consideration obligations
Dec. 31, 2012
Liabilities: Series I warrants
Dec. 31, 2011
Liabilities: Series I warrants
Reconciliation of the beginning and ending balances of items measured at fair value using significant unobservable inputs (Level 3)                  
Balance beginning of year           $ 5,978 $ 11,200 $ 11,493 $ 14,148
Total (gain) loss included in earnings           (4,112) (2,828) (3,391) (2,655)
Payments           (350) (2,394)    
Ending Balance           1,516 5,978 8,102 11,493
Other disclosures                  
Impairment charge related to an intangible asset 1,531       1,531        
Asset impairment charge       717          
Impairment charge related to an investment   $ 14,544 $ 14,544            
XML 26 R46.htm IDEA: XBRL DOCUMENT v2.4.0.6
Summary of Significant Accounting Policies (Details 2) (DCE, USD $)
In Thousands, unless otherwise specified
 3 Months Ended
Dec. 31, 2010
DCE
  
Long-Lived Assets  
Asset impairment charge $ 717
XML 27 R33.htm IDEA: XBRL DOCUMENT v2.4.0.6
Investments (Tables)
 12 Months Ended
Dec. 31, 2012
Investments  
Summary of Short-term investments

Short-term investments as of December 31, 2011 are summarized as follows:

 
   Amortized Cost   Gross Unrealized Losses   Estimated Fair Value  

Municipal bonds & notes

   $ 19,703   $ (114 ) $ 19,589  

Zero coupon bonds

     712     —     712  

Corporate bonds

     3,040     (12 )   3,028  
               

Total available-for-sale securities

     23,455     (126 )   23,329  

Certificate of deposits

     10,000     —     10,000  
               

Total short-term investments

   $ 33,455   $ (126 ) $ 33,329  
               

        Short-term investments as of December 31, 2012 are summarized as follows:

 
   Amortized Cost   Gross Unrealized Losses   Estimated Fair Value  

Municipal bonds & notes

   $ 23,755   $ (105 ) $ 23,650  

Corporate bonds

     4,557     (53 )   4,504  
               

Total available-for-sale securities

     28,312     (158 )   28,154  

Certificate of deposits

     10,021     —     10,021  
               

Total short-term investments

   $ 38,333   $ (158 ) $ 38,175  
               
XML 28 R79.htm IDEA: XBRL DOCUMENT v2.4.0.6
Fair Value Measurements (Details 3) (Level 3, USD $)
In Thousands, except Per Share data, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Contingent consideration obligation | DCF
  
Unobservable Input  
Discount rate (as a percent) 35.90%
Contingent consideration obligation | DCF | Minimum
  
Unobservable Input  
Gross profit projection 14,162
Probability of reaching target gross profit (as a percent) 0.00%
Volatility of gross profit (peer group) (as a percent) 14.60%
Contingent consideration obligation | DCF | Maximum
  
Unobservable Input  
Gross profit projection 32,641
Probability of reaching target gross profit (as a percent) 75.00%
Volatility of gross profit (peer group) (as a percent) 55.20%
Contingent consideration obligation | DCF | Simple average
  
Unobservable Input  
Volatility of gross profit (peer group) (as a percent) 31.40%
Series I Warrant | Black-Scholes Model
  
Unobservable Input  
Current market price of the company's common stock 12.45
Exercise price of the warrant 12.68
Dividend yield (as a percent) 0.00%
Remaining term of the warrant 3 years 3 months 29 days
Series I Warrant | Black-Scholes Model | Minimum
  
Unobservable Input  
Implied volatility of the Company's common stock (as a percent) 45.20%
Series I Warrant | Black-Scholes Model | Maximum
  
Unobservable Input  
Implied volatility of the Company's common stock (as a percent) 47.20%
Series I Warrant | Black-Scholes Model | Simple average
  
Unobservable Input  
Discount rate (as a percent) 0.40%
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401(k) Plan (Details) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
401(k) Plan      
Maximum percentage of base pay that can be contributed by employees through salary deferrals 90.00%    
Contribution by the company $ 1,289 $ 798 $ 551
XML 31 R57.htm IDEA: XBRL DOCUMENT v2.4.0.6
Land, Property and Equipment (Details) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Land, Property and Equipment      
Land, property and equipment, gross $ 536,514 $ 340,221  
Less: accumulated depreciation (108,337) (82,758)  
Land, property and equipment, net 428,177 257,463  
Capitalized software costs, net 17,611 5,539  
Accumulated amortization on the capitalized software costs 5,380 3,568  
Amount included in accounts payable balances 12,087 9,211  
Amortization expense related to the capitalized software costs 1,812 1,635 498
Land
      
Land, Property and Equipment      
Land, property and equipment, gross 1,476 1,198  
LNG liquefaction plants
      
Land, Property and Equipment      
Land, property and equipment, gross 93,384 93,109  
RNG plants
      
Land, Property and Equipment      
Land, property and equipment, gross 23,582 21,005  
Station equipment
      
Land, Property and Equipment      
Land, property and equipment, gross 158,447 118,613  
LNG trailers
      
Land, Property and Equipment      
Land, property and equipment, gross 13,566 13,532  
Other equipment
      
Land, Property and Equipment      
Land, property and equipment, gross 47,143 26,508  
Construction in progress
      
Land, Property and Equipment      
Land, property and equipment, gross $ 198,916 $ 66,256  
XML 32 R76.htm IDEA: XBRL DOCUMENT v2.4.0.6
Capitalized Lease Obligation and Receivables (Details 2) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2012
Capitalized Lease Obligation and Receivables  
Sales-type leases interest rate (as a percent) 4.80%
Future receipts under the leases  
2013 $ 377
2014 377
2015 377
2016 377
2017 256
Total 1,767
Less amount representing interest (193)
Present value of future minimum lease receipts $ 1,574
XML 33 R81.htm IDEA: XBRL DOCUMENT v2.4.0.6
Schedule II: Valuation and Qualifying Accounts (Details) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Allowances for Doubtful Trade Receivables
      
Movement in valuation and qualifying accounts      
Balance at the beginning of the period $ 712 $ 702 $ 898
Charges (benefit) to operations 434 344 264
Deductions (242) (334) (460)
Balance at the end of the period 904 712 702
Allowance for Doubtful Notes Receivables
      
Movement in valuation and qualifying accounts      
Balance at the beginning of the period 20 93 216
Charges (benefit) to operations 924    
Deductions (35) (73) (123)
Balance at the end of the period $ 909 $ 20 $ 93
XML 34 R77.htm IDEA: XBRL DOCUMENT v2.4.0.6
Fair Value Measurements (Details) (Fair value measured on recurring basis, USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Fair Value Measurements    
Estimated remaining life of Series I warrants 3 years 3 months 29 days  
Liabilities:    
Natural gas futures contracts $ 107 $ 2,335
Fair value of contingent consideration 1,516 5,978
Series I warrants 8,102 11,493
Minimum
    
Fair Value Measurements    
Term of traded options 3 months  
Maximum
    
Fair Value Measurements    
Term of traded options 9 months  
Certificate of deposits
    
Assets:    
Available-for-sale securities 10,021 10,000
Municipal bonds and notes
    
Assets:    
Available-for-sale securities 23,650 19,589
Zero coupon bonds and notes
    
Assets:    
Available-for-sale securities   712
Corporate bonds
    
Assets:    
Available-for-sale securities 4,504 3,028
Level 2
    
Liabilities:    
Natural gas futures contracts 107 2,335
Level 2 | Certificate of deposits
    
Assets:    
Available-for-sale securities 10,021 10,000
Level 2 | Municipal bonds and notes
    
Assets:    
Available-for-sale securities 23,650 19,589
Level 2 | Zero coupon bonds and notes
    
Assets:    
Available-for-sale securities   712
Level 2 | Corporate bonds
    
Assets:    
Available-for-sale securities 4,504 3,028
Level 3
    
Liabilities:    
Fair value of contingent consideration 1,516 5,978
Series I warrants $ 8,102 $ 11,493
XML 35 R71.htm IDEA: XBRL DOCUMENT v2.4.0.6
Commitments and Contingencies (Details 2) (USD $)
In Thousands, unless otherwise specified
 1 Months Ended 12 Months Ended
Oct. 31, 2007
gal
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Take-or-Pay LNG Supply Contracts
        
Take-or-Pay LNG Supply Contracts        
Amount paid under the contract   $ 3,821 $ 5,034 $ 4,281
Fixed commitments under the contract payable in future        
2013 through 2016   2,095    
2014   1,049    
LNG sales agreement with Desert Gas Services
        
Take-or-Pay LNG Supply Contracts        
Amount paid under the contract   8,153 7,599 4,041
Fixed commitments under the contract payable in future        
2013 through 2016   3,058    
2017   $ 2,549    
Term of contract 10 years      
Number of gallons of LNG per day 45,000      
XML 36 R25.htm IDEA: XBRL DOCUMENT v2.4.0.6
Capitalized Lease Obligation and Receivables
 12 Months Ended
Dec. 31, 2012
Capitalized Lease Obligation and Receivables  
Capitalized Lease Obligation and Receivables

(17) Capitalized Lease Obligation and Receivables

        The Company leases equipment under capital leases with a weighted-average interest rate of 7.2%. At December 31, 2012, future payments under these capital leases are as follows:

2013

   $ 2,069  

2014

     1,195  

2015

     400  

2016

     35  

2017

     36  

Thereafter

     56  
       

Total minimum lease payments

     3,791  

Less amount representing interest

     (223 )
       

Present value of future minimum lease payments

     3,568  

Less current portion

     (1,892 )
       

Capital lease obligations, less current portion

   $ 1,676  
       

        The value of the equipment under capital lease as of December 31, 2011 and 2012 was $6,802 and $6,802, with related accumulated amortization of $1,378 and $1,834, respectively.

        The Company also leases certain fueling station equipment to certain customers under sales-type leases at a weighted average effective interest rate of 4.8%. The leases are payable in varying monthly installments through February 2017.

        At December 31, 2012, future receipts under these leases are as follows:

2013

   $ 377  

2014

     377  

2015

     377  

2016

     377  

2017

     256  
       

Total

     1,767  

Less amount representing interest

     (193 )
       

 

   $ 1,574  
       
XML 37 R50.htm IDEA: XBRL DOCUMENT v2.4.0.6
Summary of Significant Accounting Policies (Details 6) (IMW)
 12 Months Ended
Dec. 31, 2012
IMW
  
Concentration of Credit Risk  
Maximum percentage of foreign trade receivables covered by accounts receivable insurance 90.00%
XML 38 R42.htm IDEA: XBRL DOCUMENT v2.4.0.6
Geographic Information (Tables)
 12 Months Ended
Dec. 31, 2012
Geographic Information  
Schedule of revenue, operating income (loss), and long-lived assets shown for each geographic

 

 

 
   2010   2011   2012  

Revenue:

                    

United States

   $ 194,512   $ 248,419   $ 286,125  

Canada

     6,158     4,800     8,364  

Other

     11,164     39,498     39,519  
               

Total revenue

   $ 211,834   $ 292,717   $ 334,008  
               

Operating income (loss):

                    

United States

   $ (7,251 ) $ (33,761 ) $ (69,030 )

Canada

     1,386     (5,844 )   (188 )

Other

     343     1,037     (1,304 )
               

Total operating income (loss)

   $ (5,522 ) $ (38,568 ) $ (70,522 )
               

Long-lived assets:

                    

United States

   $ 262,545   $ 325,386   $ 480,067  

Canada

     133,078     121,103     122,291  

Other

     2,287     3,277     3,547  
               

Total long-lived assets

   $ 397,910   $ 449,766   $ 605,905  
               

        
XML 39 R75.htm IDEA: XBRL DOCUMENT v2.4.0.6
Capitalized Lease Obligation and Receivables (Details) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2012
Dec. 31, 2011
Capitalized Lease Obligation and Receivables    
Weighted average interest rate (as a percent) 7.20%  
Value of the equipment under capital lease $ 6,802 $ 6,802
Accumulated amortization 1,834 1,378
Future payments under these capital leases    
2013 2,069  
2014 1,195  
2015 400  
2016 35  
2017 36  
Thereafter 56  
Total minimum lease payments 3,791  
Less amount representing interest (223)  
Present value of future minimum lease payments 3,568  
Less current portion (1,892)  
Capital lease obligations, less current portion $ 1,676  
XML 40 R37.htm IDEA: XBRL DOCUMENT v2.4.0.6
Long-term Debt (Tables)
 12 Months Ended
Dec. 31, 2012
Long-term Debt  
Schedule of long-term debt

 

 

 
   December 31,
2011		   December 31,
2012		  

IMW Notes

   $ 34,400   $ 23,983  

Northstar future payments

     2,388     1,848  

DCEMB notes

     585     585  

DCEMB Revenue Bonds (non recourse to the Company)

     39,400     38,700  

CHK Notes

     50,000     100,000  

SLG Notes

     150,000     149,000  

Weaver Notes

     872     680  

IMW assumed debt

     6,657     12,661  

Capital lease obligations

     5,120     3,568  
           

Total debt and capital lease obligations

     289,422     331,025  

Less amounts due within one year and short-term borrowings

     (22,925 )   (30,389 )
           

Total long-term debt and capital lease obligations

   $ 266,497   $ 300,636  
           

        
Summary of aggregate maturities of long term debt

The following is a summary of aggregate maturities of long-term debt for each of the years ending December 31:

 
   2013   2014   2015   2016   2017   Thereafter  

IMW Notes

   $ 12,448   $ 11,535   $ —   $ —   $ —   $ —  

Northstar future payments

     662     617     569     —     —     —  

DCEMB notes

     585     —     —     —     —     —  

DCEMB Revenue Bonds

     2,200     2,415     2,540     2,675     2,830     26,040  

CHK Notes

     —     —     —     —     —     100,000  

SLG Notes

     —     —     —     149,000     —     —  

Weaver Notes

     241     227     212     —     —     —  

IMW assumed debt

     12,361     300     —     —     —     —  

Capital lease obligations

     1,892     1,157     395     34     35     55  
                           

Total

   $ 30,389   $ 16,251   $ 3,716   $ 151,709   $ 2,865   $ 126,095  
                           
XML 41 R52.htm IDEA: XBRL DOCUMENT v2.4.0.6
Acquisitions (Details 2) (USD $)
In Thousands, unless otherwise specified
 3 Months Ended 12 Months Ended 0 Months Ended 1 Months Ended 2 Months Ended 12 Months Ended 0 Months Ended
Dec. 31, 2010
Dec. 31, 2012
Dec. 31, 2011
Dec. 15, 2010
Northstar
item
Dec. 15, 2010
Northstar
Minimum
Dec. 15, 2010
Northstar
Maximum
Jun. 30, 2009
Operating and Maintenance Contracts
item
May 31, 2009
Operating and Maintenance Contracts
item
Jun. 30, 2009
Operating and Maintenance Contracts
item
Dec. 31, 2010
Operating and Maintenance Contracts
Dec. 31, 2011
BAF
Oct. 01, 2009
BAF
Oct. 01, 2009
BAF
Minimum
Oct. 01, 2009
BAF
Maximum
Acquisitions                            
Cash payment       $ 7,414     $ 5,645   $ 5,645          
Number of annual payments       5                    
Annual payment required       700                    
Maximum aggregate retention bonus required to be paid to key employees, as a part of purchase consideration       4,000                    
Number of annual retention bonus installments required to be paid to key employees, as a part of purchase consideration       4                    
Estimate of fair values of assets acquired and liabilities assumed                            
Current assets       4,434                    
Property, plant and equipment       941                    
Identifiable intangible assets       3,350     5,108   5,108     10,660    
Goodwill       5,228               774    
Total assets acquired       13,953                    
Liabilities assumed       (3,648)               (3,060)    
Total purchase price       10,305               11,567    
Purchase price allocated to the identifiable intangible assets       2,250                    
Identifiable intangible assets, estimated useful lives         1 year 10 years     8 years       1 year 6 months 8 years
Purchase price allocated to trademarks, which the management believes to have an indefinite useful life       1,100                    
Number of contracts acquired             2 2 4          
Price allocated to tangible assets             537   537          
Customer-owned inventory recorded as an asset             986   986          
Customer-owned inventory recorded as an liability             986   986          
Impairment charge related to an intangible asset 1,531                 1,531        
Debt acquired                       3,790    
Contingent consideration payment   350 2,394               2,159      
Cash acquired                       4,717    
Goodwill       $ 5,228               $ 774    
Percentage of amount to be paid to purchase remaining interest   50.00%                        
XML 42 R67.htm IDEA: XBRL DOCUMENT v2.4.0.6
Income Taxes (Details) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Income (loss) before income taxes      
U.S. $ (91,608) $ (30,002) $ (6,048)
Foreign (7,960) (18,156) 1,839
Income (loss) before income taxes, total (99,568) (48,158) (4,209)
Current:      
Federal 269 206 (1,753)
State 302 296 255
Foreign (61) 396 117
Total current 510 898 (1,381)
Deferred:      
Federal (20,646) (8,012) (4,361)
State (3,445) (1,724) (966)
Foreign (3,053) (4,075) 145
Change in valuation allowance 27,928 12,210 5,127
Total deferred 784 (1,601) (55)
Income tax expense (benefit) 1,294 (703) (1,436)
Reconciliation of the income tax provision      
Federal income tax rate (as a percent) 35.00% 35.00% 35.00%
Computed expected tax expense (benefit) (34,849) (16,855) (1,473)
State and local taxes, net of federal benefit 121 202 174
Nondeductible expenses 5,194 3,073 (2,615)
Tax rate differential on foreign earnings (717) 5,273 (580)
Refund of alternative minimum taxes     (1,323)
Tax credits   (834) (875)
Other (1,563) (148) 129
Change in valuation allowance 33,108 8,586 5,127
Income tax expense (benefit) 1,294 (703) (1,436)
Deferred tax assets:      
Accrued expenses 2,303 1,163  
Sales-type leases 500 212  
Alternative minimum tax and general business credits 3,297 3,470  
Derivative loss 1,831 2,363  
Stock option expense 15,259 11,611  
Other 644 1,223  
Loss carryforwards 79,819 55,212  
Total deferred tax assets 103,653 75,254  
Less valuation allowance (81,257) (53,329)  
Net deferred tax assets 22,396 21,925  
Deferred tax liabilities:      
Depreciation and amortization-domestic (20,291) (19,724)  
Depreciation and amortization-foreign (1,045) (928)  
Partnership income (2,071) (1,500)  
Total deferred tax liabilities (23,407) (22,152)  
Net deferred tax assets (liabilities) $ (1,011) $ (227)  
XML 43 R61.htm IDEA: XBRL DOCUMENT v2.4.0.6
Long-term Debt (Details)
 0 Months Ended 1 Months Ended 1 Months Ended 1 Months Ended 0 Months Ended 1 Months Ended 0 Months Ended 1 Months Ended 0 Months Ended 1 Months Ended
Dec. 31, 2012
USD ($)
Dec. 31, 2011
USD ($)
Aug. 15, 2008
Facility A Loan
USD ($)
Aug. 15, 2008
Facility B Loan
USD ($)
Mar. 31, 2011
Facility B Loan
USD ($)
Nov. 30, 2010
Facility B Loan
USD ($)
Aug. 31, 2010
A Line of Credit
Oct. 07, 2009
A Line of Credit
USD ($)
Aug. 15, 2008
DCE Loan
USD ($)
Jan. 31, 2011
DCEMB Revenue Bonds
item
Dec. 31, 2012
DCEMB Revenue Bonds
USD ($)
Dec. 31, 2011
DCEMB Revenue Bonds
USD ($)
Mar. 25, 2011
DCEMB Revenue Bonds
USD ($)
Jan. 31, 2011
DCEMB Revenue Bonds
Minimum
USD ($)
Sep. 07, 2010
IMW Notes
USD ($)
item
Sep. 07, 2010
IMW Notes
CAD
Feb. 28, 2013
IMW Notes
USD ($)
Feb. 28, 2013
IMW Notes
CAD
Oct. 31, 2012
IMW Notes
USD ($)
Aug. 31, 2012
IMW Notes
USD ($)
Jan. 31, 2012
IMW Notes
CAD
Jan. 31, 2011
IMW Notes
USD ($)
Dec. 15, 2010
Northstar future payments
USD ($)
item
Dec. 31, 2012
Northstar future payments
USD ($)
Dec. 31, 2011
Northstar future payments
USD ($)
Oct. 03, 2011
Weaver Notes
USD ($)
item
May 31, 2012
Weaver Notes
USD ($)
Mar. 25, 2011
Dallas Clean Energy McCommas Bluff, LLC
Aug. 15, 2008
Dallas Clean Energy, LLC ("DCE")
Oct. 31, 2012
ServoTech
USD ($)
Apr. 30, 2012
ServoTech
USD ($)
Feb. 25, 2011
ServoTech
USD ($)
Long-term Debt                                                                
Interest acquired (as a percent)                                                         70.00%     19.90%
Ownership interest (as a percent)                                                       70.00%        
Debt issuance amount     $ 18,000,000           $ 14,000,000       $ 40,200,000                                      
Debt amount       12,000,000       20,000,000                                                
Option to extend the maturity date from August 14, 2011             1 year                                                  
Unused facility fee on the unused portion of credit facility (as a percent)             0.10%                                                  
Percentage of principal required to be paid as per debt repayment schedule       20.00%                                                        
Principal amount required to be paid as per debt repayment schedule       2,800,000                                                        
Prior annual payment of principal delayed           2,059,000                                                    
Coupon interest rate (as a percent)                         6.60%                                      
Loan repayment         8,000,000                                                      
Debt Service Coverage Ratio, number of calendar quarters measured                   4                                            
Required debt service coverage ratio for the most recent four calendar quarters                           1.25                                    
Projected debt service coverage ratio for the next four calendar quarters                           1.25                                    
Debt covenant period considered for cash on hand                           35 days                                    
Debt covenant value, cash on hand                           1,300,000                                    
Long term restricted cash 13,208,000 54,804,000                 952,000 14,482,000                                        
Short-term restricted cash 8,445,000 4,792,000                 7,776,000 3,555,000                                        
Number of annual payments                             4 4             5     4            
Annual payment required                                             700,000     250,000            
Annual payment required                             12,500,000                                  
Annual cash required to be paid on debt instrument                               5,000,000                                
Number of annual payments made                                             2                  
Amount paid                                   5,000,000     5,000,000 5,000,000   700,000 700,000   125,000          
Common stock issued on debt instrument                                 7,500,000   3,750,000 3,750,000   7,500,000                    
Cash and/or common stock required to be paid or issued on debt instrument                             7,500,000                                  
Cash paid in connection with acquisition                                                   $ 1,000,000       $ 1,400,000 $ 1,400,000 $ 1,200,000
XML 44 R47.htm IDEA: XBRL DOCUMENT v2.4.0.6
Summary of Significant Accounting Policies (Details 3) (USD $)
In Thousands, unless otherwise specified
 3 Months Ended 12 Months Ended
Dec. 31, 2010
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Goodwill and intangible assets        
Impairment charge related to an intangible asset $ 1,531      
Total intangible assets   125,175 121,262  
Less accumulated amortization   (30,632) (19,757)  
Foreign currency rate change   4,739 598  
Net intangible assets   99,282 102,103  
Carrying value of trademark of indefinite useful life   1,200 1,200  
Amortization expense   10,875 10,071 5,915
Estimated amortization expense        
2013   9,217    
2014   8,838    
2015   8,586    
2016   8,504    
2017   7,733    
Technology
        
Goodwill and intangible assets        
Total intangible assets   57,595 56,026  
Technology | Minimum
        
Goodwill and intangible assets        
Estimated useful lives   2 years    
Technology | Maximum
        
Goodwill and intangible assets        
Estimated useful lives   20 years    
Lease agreements
        
Goodwill and intangible assets        
Total intangible assets   21,645 21,045  
Lease agreements | Minimum
        
Goodwill and intangible assets        
Estimated useful lives   1 year    
Lease agreements | Maximum
        
Goodwill and intangible assets        
Estimated useful lives   16 years    
Customer relationships
        
Goodwill and intangible assets        
Total intangible assets   23,334 21,590  
Customer relationships | Minimum
        
Goodwill and intangible assets        
Estimated useful lives   1 year    
Customer relationships | Maximum
        
Goodwill and intangible assets        
Estimated useful lives   8 years    
Acquired contracts
        
Goodwill and intangible assets        
Total intangible assets   13,075 13,075  
Acquired contracts | Minimum
        
Goodwill and intangible assets        
Estimated useful lives   1 year    
Acquired contracts | Maximum
        
Goodwill and intangible assets        
Estimated useful lives   10 years    
Trademark and tradenames
        
Goodwill and intangible assets        
Total intangible assets   7,400 7,400  
Trademark and tradenames | Minimum
        
Goodwill and intangible assets        
Estimated useful lives   2 years    
Trademark and tradenames | Maximum
        
Goodwill and intangible assets        
Estimated useful lives   20 years    
Non-compete agreements
        
Goodwill and intangible assets        
Estimated useful lives   3 years    
Total intangible assets   $ 2,126 $ 2,126  
XML 45 R9.htm IDEA: XBRL DOCUMENT v2.4.0.6
Summary of Significant Accounting Policies
 12 Months Ended
Dec. 31, 2012
Summary of Significant Accounting Policies  
Summary of Significant Accounting Policies

(1) Summary of Significant Accounting Policies

The Company

        Clean Energy Fuels Corp., together with its majority and wholly owned subsidiaries (hereinafter collectively referred to as the "Company"), is engaged in the business of selling natural gas fueling solutions to its customers, primarily in the United States and Canada.

        Clean Energy has a broad customer base in a variety of markets, including trucking, airports, taxis, refuse and public transit. The Company, builds, operates, maintains or supplies approximately 348 natural gas fueling locations in thirty-two states within the United States, and in British Columbia and Ontario within Canada. The Company also generates revenue through operation and maintenance ("O&M") agreements with certain customers, through building and selling or leasing natural gas fueling stations to its customers, through manufacturing and servicing natural gas fueling compressors and related equipment, providing natural gas vehicle conversions, providing design and engineering services for natural gas engine systems, processing and selling renewable natural gas ("RNG"), and through financing its customers' vehicle purchases and selling tradable credits the Company generates by selling natural gas and RNG as a vehicle fuel, including credits ("LCFS Credits") under the California low carbon fuel standard.

Basis of Presentation

        The 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 in accordance with U.S. generally accepted accounting principles ("US GAAP"). All intercompany accounts and transactions have been eliminated in consolidation.

Use of Estimates

        The preparation of consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements and revenues and expenses recorded during the reporting period. Actual results could differ from those estimates. Current economic conditions may require the use of additional estimates and these estimates may be subject to a greater degree of uncertainty as a result of the uncertain economy.

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.

Fair Value of Financial Instruments

        The carrying values of the Company's financial instruments, including cash and cash equivalents, accounts and other receivables, notes receivable, accounts payable, accrued expenses and other current liabilities, capital lease obligations and notes payable approximate fair value.

Inventories

        Inventories are stated at the lower of cost or market value on a first-in, first out basis. Management's estimate of market value includes a provision for slow-moving or obsolete inventory based upon inventory on hand and forecasted demand.

        Inventories consisted of the following as of December 31, 2011 and 2012:

 
   2011   2012  

Raw materials and spare parts

   $ 30,177   $ 30,137  

Work in process

     2,310     5,835  

Finished goods

     2,800     2,180  
           

Total

   $ 35,287   $ 38,152  
           

Property and Equipment

        Property and equipment are recorded at cost. Depreciation and amortization are recognized over the estimated useful lives of the assets using the straight-line method. The estimated useful lives of depreciable assets are twenty years for LNG liquefaction plant assets, ten years for station equipment and LNG trailers, and three to seven years for all other depreciable assets. Leasehold improvements are amortized over the shorter of their estimated useful lives or related lease terms. Periodically, the Company receives grant funding to assist in the financing of natural gas fueling station construction. The Company records the grant proceeds as a reduction of the cost of the respective asset. Total grant proceeds received were approximately $831, $3,090, and $5,908 for the years ended December 31, 2010, 2011 and 2012, respectively.

Long-Lived Assets

        The Company reviews long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying value of an asset may not be recoverable. Recoverability of long-lived assets to be held and used is measured by a comparison of the carrying amount of an asset to future net undiscounted cash flows expected to be generated by the asset or asset group. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. Assets to be disposed of are reported at the lower of the carrying amount or the fair value less costs to sell.

        During the fourth quarter of 2010, the Company's majority-owned subsidiary, Dallas Clean Energy, LLC ("DCE"), recorded an impairment charge of $717 related to equipment that was replaced as part of its expansion of the McCommas Bluff landfill in Dallas, Texas.

Goodwill and Intangible Assets

        Goodwill represents the excess of costs incurred over the fair value of the net assets of acquired businesses. Goodwill and intangible assets acquired in a business combination and determined to have an indefinite useful life are not amortized. In 2011, the Company changed its annual impairment testing to October 1 of each year. Beginning on October 1, 2011, the Company performed its test for Goodwill impairment under the amended guidance issued by the FASB in Accounting Standards Update ("ASU") 2011-08, Testing for Goodwill Impairment, issued in September 2011, which the Company chose to early adopt, effective October 1, 2011. Under the amended requirements of ASU 2011-08, an entity is not required to quantitatively determine a reporting unit's fair value, if it concludes, based upon a qualitative assessment, that it is not more likely than not that the reporting unit's fair value is less than its carrying amount. A qualitative assessment is an option available on an individual reporting unit basis and is an unconditional alternative to Step 1 of the goodwill impairment test. A reporting entity can choose to perform either Step 1 or a qualitative assessment in subsequent reporting periods. If the Company does conduct a Step 1 test, the Company looks at its projected future cash flows and its market capitalization for its respective operations. In these instances, to the extent the Company's projected future cash flows do not materialize as planned or its market capitalization decreases, the Company could be forced to take an impairment charge in future periods.

        Beginning on October 1, 2012, the Company performed its test for indefinite-lived intangible assets impairment under the amended guidance issued by the FASB in ASU 2012-02, Testing Indefinite-Lived Intangible Assets for Impairment, issued in July 2012, which the Company chose to early adopt, effective October 1, 2012. The amended requirements of ASU 2012-02 provided a similar framework for testing indefinite-lived intangible assets for impairment as the ASU 2011-08 does for testing goodwill for impairment.

        There were no impairment charges for goodwill or indefinite-lived intangible asset resulting from the October 1, 2011 or 2012 impairment testing, and no events have occurred subsequent to October 1, 2012 which indicates impairment may have occurred.

        Intangible assets with finite useful lives are amortized over their respective estimated useful lives using the straight-line method. The estimated useful lives of intangible assets with finite useful lives are two to 20 years for technology, one to 16 years for lease agreements, one to eight years for customer relationships, one to 10 years for acquired contracts, two to 20 years for trademarks and trade names, and three years for non-compete agreements. The intangible assets with finite useful lives are reviewed for impairment whenever events or changes in circumstances indicate that the carrying value of the asset may not be recoverable.

        During the fourth quarter of 2010, as a result of losing a competitive bid to a customer, the Company recorded an impairment charge of $1,531 related to an intangible asset. The Company's intangible assets as of December 31, 2011 and 2012 were as follows:

 
   2011   2012  

Technology

   $ 56,026   $ 57,595  

Lease agreements

     21,045     21,645  

Customer relationships

     21,590     23,334  

Acquired contracts

     13,075     13,075  

Trademark and tradenames

     7,400     7,400  

Non-compete agreements

     2,126     2,126  
           

Total intangible assets

     121,262     125,175  

Less accumulated amortization

     (19,757 )   (30,632 )

Foreign currency rate change

     598     4,739  
           

Net intangible assets

   $ 102,103   $ 99,282  
           

        Included above is a trademark of indefinite useful life with carrying value of $1,200 as of December 31, 2011 and 2012, respectively.

        Amortization expense for intangible assets was $5,915, $10,071, and $10,875 for the years ended December 31, 2010, 2011 and 2012, respectively. Estimated amortization expense for the five years succeeding the year ended December 31, 2012 is approximately $9,217, $8,838, $8,586, $8,504 and $7,733, respectively.

Warranty Liability

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

 
   December 31, 2011   December 31, 2012  

Warranty liability at beginning of year

   $ 2,338   $ 3,130  

Costs accrued for new warranty contracts and changes in estimates for pre-existing warranties

     3,208     3,733  

Service obligations honored

     (2,416 )   (4,198 )
           

Warranty liability at end of year

   $ 3,130   $ 2,665  
           

Asset Retirement Obligations

        The Company recognizes the fair value of a liability for an asset retirement obligation in the period in which the liability is incurred or becomes reasonably estimable and if there is a legal obligation to restore or remediate the property at the end of the asset life or at the end of the lease term. All of the Company's fueling and storage equipment is located above-ground. The liability amounts are based upon future retirement cost estimates and incorporate many assumptions such as the costs to restore the property, future inflation rates, and the adjusted risk free rate of interest. When the liability is initially recorded, the Company capitalizes the cost by increasing the related property and equipment balance. Over time, the liability is increased and expense is recognized for the change in the present value of the obligation, and the initial capitalized cost is depreciated over the useful life of the asset.

        The following table summarizes the activity of the asset retirement obligation, of which $964 and $1,215 is included in other long-term liabilities, with the remaining current portion included in accrued liabilities, as of December 31, 2011 and 2012, respectively:

 
   2011   2012  

Beginning balance

   $ 1,128   $ 1,179  

Liabilities incurred

     8     74  

Liabilities settled

     (3 )   —  

Accretion expense

     46     60  
           

Ending balance

   $ 1,179   $ 1,313  
           

Revenue Recognition

        The Company recognizes revenue on gas sales and O&M services in accordance with US GAAP, which requires that four basic criteria must be met before revenue can be recognized: (i) persuasive evidence of an arrangement exists; (ii) delivery has occurred and title and the risks and rewards of ownership have been transferred to the customer or services have been rendered; (iii) the price is fixed or determinable; and (iv) collectability is reasonably assured. Applying these factors, the Company typically recognizes revenue from the sale of natural gas fuel at the time the fuel is dispensed or, in the case of LNG sales agreements, delivered to the customers' storage facilities. The Company recognizes revenue from O&M agreements as the related services are provided.

        In certain transactions with Clean Energy customers, the Company agrees to provide multiple products or services, including construction of a station, providing O&M to the station, and sale of fuel to the customer. The Company evaluates the separability of revenues based on FASB authoritative guidance, which provides a framework for establishing whether or not a particular arrangement with a customer has one or more revenue elements. In 2010, the Company elected to apply newly issued FASB authoritative guidance that allows it to use a combination of internal and external objective and reliable evidence to develop management's best estimate of the fair value of the contract elements. If the arrangement contains a lease, the Company uses the existing evidence of fair value to separate the lease from the other elements in the arrangement. The arrangement's consideration that is fixed or determinable is then allocated to each separate unit of accounting based on the estimated relative selling price of each deliverable, which is determined based on the historical data derived from the Company's stand alone projects. The revenue allocated to the construction of the station is recognized using the completed-contract method. The revenue allocated to the O&M and sale of fuel is recognized ratably over the term of the arrangement.

        The Company recognizes revenue related to its leasing activities in accordance with FASB authoritative guidance. The Company's existing station leases are sales-type leases, giving rise to profit at the delivery of the leased station. Unearned revenue is amortized into income over the life of the lease using the effective-interest method. For these arrangements, the Company recognizes gas sales and O&M service revenues as earned from the customer on a volume-delivered basis.

        The Company typically recognizes revenue on fueling station construction projects where it sells the station to the customer using the completed-contract method because the projects are short-term and the results of operations reported on the completed-contract basis would not vary materially from those resulting from the use of the percentage-of-completion method. The construction contract is considered to be substantially completed at the earlier of customer acceptance of the fueling station or the time when the fuel dispensing activities begin. When applicable, multi-station construction contracts are segmented into phases as negotiated with customers. Gross margin related to each phase is recognized at its substantial completion. IMW Industries, Ltd. ("IMW") and Wyoming Northstar Incorporated, Southstar, LLC, and M&S Rental LLC (collectively "Northstar") use the percentage-of-completion method of accounting to recognize revenue because their projects are small and they have been able to demonstrate that they can reasonably estimate costs to complete. In these circumstances, revenue is recognized based on costs incurred in relation to total estimated costs to be incurred for a project.

        The Company recognizes revenue on RNG sales and vehicle sales when it transfers title of the gas or vehicle to its customer.

Volumetric Excise Tax Credits ("VETC")

        The Company records its VETC credits as revenue as the credits are fully refundable and do not need to offset income tax liabilities to be received. VETC revenues for the years ended December 31, 2010 and 2011 were $16,042, and $17,889, respectively. During 2010, the legislation providing for VETC was reinstated in the fourth quarter of 2010 and made retroactive to January 1, 2010. The VETC legislation expired on December 31, 2011, but was made retroactive to January 1, 2012 and extended to December 31, 2013 in January 2013 (see note 19). Such credits for 2012 will be recognized in the first quarter of 2013.

LNG Transportation Costs

        The Company records the costs incurred to transport LNG to its customers in the line item cost of sales in the accompanying statements of operations.

Advertising Costs

        Advertising costs are expensed as incurred. Advertising costs amounted to $1,260, $1,559, and $1,340 for the years ended December 31, 2010, 2011 and 2012, respectively.

Stock-based Compensation

        The Company recognizes compensation expense for all stock-based payment arrangements, net of an estimated forfeiture rate, over the requisite service period of the award. For stock options, the Company determines the grant date fair value using the Black-Scholes option-pricing model which requires the input of certain assumptions, including the expected life of the stock-based payment awards, stock price volatility and risk-free interest rates.

Foreign Currency Translation

        In accordance with FASB authoritative guidance, the Company uses the local currency as the functional currency of its foreign subsidiary. Accordingly, all assets and liabilities outside the United States are translated into U.S. dollars at the rate of exchange in effect at the balance sheet date. Revenue and expense items are translated at the weighted-average exchange rates prevailing during the period. Net foreign currency translation adjustments are recorded as accumulated other comprehensive income (loss) in stockholders' equity.

        Foreign currency transactions occur when there is a transaction denominated in other than the respective entity's functional currency. The Company records the changes in the exchange rate for these transactions in the consolidated statements of operations. For the fiscal years ended December 31, 2010, 2011 and 2012, foreign exchange transaction gains and (losses) were included in other income (expense) and were $1,902, $(596), and $678, respectively.

Income Taxes

        Income taxes are computed using the asset and liability method. Under this method, deferred income taxes are recognized by applying enacted statutory tax rates applicable to future years to differences between the tax bases and financial reporting amounts of existing assets and liabilities. Valuation allowances are established when it is more likely than not that such deferred tax assets will not be realized.

        The Company has a recognition threshold and a measurement attribute for the financial statement recognition and measurement of tax positions taken or expected to be taken in a tax return. For those benefits to be recognized, a tax position must be more likely than not to be sustained upon examination by taxing authorities based on the technical merits of the position. The amount recognized is measured as the largest amount of benefit that has a greater than 50 percent likelihood of being realized upon ultimate settlement. The Company recognizes potential accrued interest and penalties related to unrecognized tax benefit in income tax expense.

Net Loss Per Share

        Basic net loss per share is computed by dividing net loss attributable to Clean Energy by the weighted-average number of common shares and common shares issuable for little or no cash consideration outstanding during the period. Diluted net loss per share is computed by dividing net loss attributable to Clean Energy by the weighted-average number of common shares and common shares issuable for little or no cash consideration outstanding and potentially dilutive securities outstanding during the period. Potentially dilutive securities include stock options and warrants, in 2011 and 2012, convertible notes, and in 2012, restricted stock units. The dilutive effect of stock options and warrants is computed under the treasury stock method. Potentially dilutive securities are excluded from the computations of diluted net loss per share if their effect would be antidilutive. In 2012, 5,000,000 shares of common stock related to the GE Warrant were included in the basic and dilutive net loss per share calculation.

        The following potentially dilutive securities have been excluded from the diluted net loss per share calculations because their effect would have been antidilutive:

 
   2010   2011   2012  

Stock options

     10,433,551     10,683,303     12,083,677  

Warrants

     17,130,682     2,130,682     2,130,682  

Convertibles notes

     —     13,164,557     16,262,226  

Restricted stock units

     —     —     1,545,000  

Derivative Financial Instruments

        The Company, in an effort to manage its natural gas commodity price risk exposures related to certain contracts, utilizes derivative financial instruments. The Company, from time to time, enters into natural gas futures contracts that are over-the-counter swap transactions that convert its index-based gas supply arrangements to fixed price arrangements. The Company accounts for its derivative instruments in accordance with FASB authoritative guidance for derivative instruments and hedging activities, which requires the recognition of all derivatives as either assets or liabilities in the consolidated balance sheet and the measurement of those instruments at fair value.

        The Company's futures contracts at December 31, 2012 are being accounted for as cash flow hedges and are being used to mitigate the Company's exposure to changes in the price of natural gas and not for speculative purposes. At December 31, 2012, all of the Company's futures contracts qualified for hedge accounting.

        The counter-party to the Company's derivative transactions is a high credit quality counterparty; however, the Company is subject to counterparty credit risk to the extent the counterparty to the derivatives is unable to meet its settlement commitments. The Company manages this credit risk by minimizing the number and size of its derivative contracts. The Company actively monitors the creditworthiness of its counterparties and records valuation adjustments against the derivative assets to reflect counterparty risk, if necessary. The counter-party is also exposed to credit risk of the Company, which requires the Company to provide cash deposits as collateral.

Comprehensive Income (Loss)

        Comprehensive income (loss) is defined as the change in equity (net assets) of a business enterprise during the period from transactions and other events and circumstances from non-owner sources. The difference between net income and comprehensive income for the years ended December 31, 2010, 2011, and 2012 was primarily comprised of the Company's foreign currency translation adjustments and unrealized gains (losses) on futures contracts.

Concentration of Credit Risk

        Credit is extended to all customers based on financial condition, and collateral is generally not required. Concentrations of credit risk with respect to trade receivables are limited because of the large number of customers comprising the Company's customer base and dispersion across many different industries and geographies. However, certain international customers have historically been slower to pay on trade receivables. Accordingly, the Company continuously monitors collections and payments from its customers and maintains a provision for estimated credit losses based upon its historical experience and any specific customer collection issues that it has identified. In addition, through Export Development Canada, IMW maintains accounts receivable insurance on a substantial portion of its foreign trade receivables, which covers up to 90% of the related outstanding balance. Although such credit losses have historically been within the Company's expectations and the provisions established, the Company cannot guarantee that it will continue to experience the same credit loss rates that it has in the past.

Recently Adopted Accounting Changes and Recently Issued and Adopted Accounting Standards

        On January 1, 2012, the Company adopted changes issued by the FASB to conform existing guidance regarding fair value measurement and disclosure between GAAP and International Financial Reporting Standards. These changes both clarify the FASB's intent about the application of existing fair value measurement and disclosure requirements and amend certain principles or requirements for measuring fair value or for disclosing information about fair value measurements. The clarifying changes relate to the application of the highest and best use and valuation premise concepts, measuring the fair value of an instrument classified in a reporting entity's shareholders' equity, and disclosure of quantitative information about unobservable inputs used for Level 3 fair value measurements. The amendments relate to measuring the fair value of financial instruments that are managed within a portfolio, application of premiums and discounts in a fair value measurement, and additional disclosures concerning the valuation processes used and sensitivity of the fair value measurement to changes in unobservable inputs for those items categorized as Level 3, a reporting entity's use of a nonfinancial asset in a way that differs from the asset's highest and best use, and the categorization by level in the fair value hierarchy for items required to be measured at fair value for disclosure purposes only. Other than the additional disclosure requirements (see note 18), the adoption of these changes had no impact on the consolidated financial statements.

        On January 1, 2012, the Company adopted changes issued by the FASB to the presentation of comprehensive income. These changes give an entity the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. The option to present components of other comprehensive income as part of the statement of changes in stockholders' equity was eliminated. The items that must be reported in other comprehensive income or when an item of other comprehensive income must be reclassified to net income were not changed. Additionally, no changes were made to the calculation and presentation of earnings per share. Management elected to present the two-statement option. Other than the change in presentation, the adoption of these changes had no impact on the consolidated financial statements.

        On October 1, 2012, the Company early adopted ASU 2012-02, Intangibles—Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment. The update simplifies the guidance for testing the decline in the realizable value (impairment) of indefinite-lived intangible assets other than goodwill. The new guidance allows an entity the option to first assess qualitative factors to determine whether it is necessary to perform the quantitative impairment test. An entity electing to perform a qualitative assessment is no longer required to calculate the fair value of an indefinite-lived intangible asset unless the entity determines, based on a qualitative assessment, that it is more likely than not that the asset is impaired. The adoption of these changes had no impact on the consolidated financial statements.

        On October 1, 2012, the FASB issued ASU 2012-04, Technical Corrections and Improvements. The amendments represent changes to clarify the Accounting Standards Codification (ASC), correct unintended application of guidance, or make minor improvements to the ASC that are not expected to have a significant effect on current accounting practice. The Company does not expect the adoption of these changes to have a material impact on its consolidated financial statements.
XML 46 R62.htm IDEA: XBRL DOCUMENT v2.4.0.6
Long-term Debt (Details 2)
 0 Months Ended 0 Months Ended 0 Months Ended 0 Months Ended 0 Months Ended 0 Months Ended 0 Months Ended 1 Months Ended 0 Months Ended 0 Months Ended 0 Months Ended
Dec. 31, 2012
USD ($)
Dec. 31, 2011
USD ($)
Sep. 07, 2010
IMW Lines of Credit
Minimum
CAD
Sep. 07, 2010
IMW Lines of Credit
January 1, 2012 through March 31, 2012
Maximum
Sep. 07, 2010
IMW Lines of Credit
April 1, 2012 through June 30, 2012
Maximum
Sep. 07, 2010
IMW Lines of Credit
July 1, 2012 and thereafter
Maximum
Sep. 07, 2010
IMW Lines of Credit
Until March 31, 2012
Minimum
Sep. 07, 2010
IMW Lines of Credit
April 1, 2012 and thereafter
Minimum
Jul. 04, 2012
IMW assumed operating line of credit
CAD
Sep. 07, 2010
IMW assumed operating line of credit
HSBC's prime rate
Sep. 07, 2010
IMW assumed operating line of credit
HSBC's U.S. base rate
Sep. 07, 2010
IMW assumed operating line of credit
LIBOR
Sep. 07, 2010
Demand revolving line of credit
CAD
Sep. 07, 2010
Demand revolving bank guarantee and standby letter of credit line
CAD
Sep. 07, 2010
IMW bank guarantee line
CAD
Sep. 07, 2010
IMW forward exchange contract line
CAD
Sep. 07, 2010
IMW Renminbi operating line of credit
CAD
Sep. 07, 2010
IMW Renminbi operating line of credit
CNY
Sep. 07, 2010
IMW Renminbi sub-limit line of credit
CNY
Sep. 07, 2010
IMW Renminbi line of credit
CNY
Sep. 07, 2010
IMW Bengali Taka operating line of credit
BDT
Sep. 07, 2010
IMW Bengali Taka operating line of credit
CAD
Sep. 07, 2010
IMW Columbian Peso operating line of credit
CAD
Sep. 07, 2010
IMW Columbian Peso operating line of credit
COP
Sep. 07, 2010
IMW Columbian Peso operating line of credit
Minimum
Sep. 07, 2010
IMW Columbian Peso operating line of credit
Maximum
Jul. 11, 2011
CHK Notes
USD ($)
D
item
Dec. 31, 2012
CHK Notes
USD ($)
Dec. 31, 2011
CHK Notes
USD ($)
Jul. 11, 2011
CHK Notes
Minimum
item
Jul. 11, 2011
CHK Notes
Maximum
USD ($)
Aug. 24, 2011
SLG Notes
USD ($)
D
Apr. 30, 2012
SLG Notes
Common stock
USD ($)
Aug. 24, 2011
SLG Notes
Minimum
item
Aug. 24, 2011
SLG Notes
Maximum
Mar. 01, 2012
SLG Notes
Baytree Investments (Mauritius) Pte Ltd
USD ($)
Nov. 07, 2012
GE Credit Agreement
USD ($)
item
Nov. 07, 2012
GE Credit Agreement
Maximum
Nov. 07, 2012
GE Credit Agreement
Maximum
Common stock
GE Warrant
Nov. 07, 2012
GE Credit Agreement
LIBOR
Nov. 07, 2012
GE Credit Agreement
LIBOR
Minimum
Long-term Debt                                                                                  
Line of credit limit                 13,000,000       2,000,000 1,115,000 3,000,000 13,750,000 789,000 5,000,000 5,000,000 5,000,000 16,750,000 209,000 95,000 170,000,000                         $ 200,000        
Debt, variable interest rate basis                   HSBC's Prime Rate HSBC's U.S. Base Rate LIBOR         6 month People's Bank of China 6 month People's Bank of China         Colombia benchmark rate Colombia benchmark rate                               LIBOR LIBOR
Percentage of margin added to reference rate to determine interest rate on debt                   1.00% 1.00% 2.25%         2.50% 2.50%             7.00% 12.00%                           7.00% 1.00%
Commitment received, limit of debt securities to be purchased                                                             150,000,000 150,000,000                  
Interest rate (as a percent)                                         14.00% 14.00%         7.50%         7.50%                  
Debt covenant, debt to tangible net worth ratio       3.75 3.5 3.0                                                                      
Debt covenant, tangible net worth     7,000,000                                                                            
Debt covenant, current assets to current liabilities ratio             1.15 1.25                                                                  
Number of convertible promissory notes to be issued                                                     3                            
Principal amount of each debt instrument to be issued                                                     50,000,000                            
Principal amount transferred                                                                       24,000,000          
Conversion price of shares (in dollars per share)                                                     $ 15.80         $ 15.00                  
Percentage of the trade price of the entity's common stock that the conversion price must be at premium in order for the notes to be convertible (as a percent)                                                     40.00%         40.00%                  
Number of consecutive trading days used to determine the conversion obligation on the notes                                                     30 days         30 days                  
Number of days within 30 consecutive trading days in which the trade price of the entity's common stock must be at premium of the conversion price for the notes to be convertible                                                     20         20                  
Amount of principal and accrued interest under debt conversion                                                                 1,003,000                
Common stock issued upon conversion of debt (in shares)                                                                 66,888                
Period during which the debt instrument principal balance is required to be paid                                                     7 years         5 years                  
Long term restricted cash related to debt instrument $ 13,208,000 $ 54,804,000                                                   $ 12,256,000 $ 40,322,000                        
Number of registration statements required to be filed under Registration Rights Agreement                                                           1       1              
Number of underwritten offerings in which the entity would be required to participate under Registration Rights Agreement                                                           1       1              
Monthly liquidated damages expressed as a percentage of principal amount of debt instrument under Registration Rights Agreement (as a percent)                                                     0.75%         0.75%                  
Annual liquidated damages limit expressed as a percentage of aggregate principal amount of debt instrument under Registration Rights Agreement (as a percent)                                                                     4.00%            
Number of wholly owned subsidiaries through which the entity entered into a financing arrangement                                                                         2        
Number of LNG production facilities being financed                                                                         2        
LNG production facilities expected production capacity (in gallons per day)                                                                         250,000        
Project completion period after the funding of the initial loans                                                                           30 months      
Amortization period following conversion into term loan                                                                           8 years      
Percentage of the budgeted costs of the Projects which the Company agreed to pay                                                                           25.00%      
Number of shares that can be purchased upon exercise of warrant                                                                             5,000,000    
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Capitalized Lease Obligation and Receivables (Tables)
 12 Months Ended
Dec. 31, 2012
Capitalized Lease Obligation and Receivables  
Schedule of future payments under the capital leases

At December 31, 2012, future payments under these capital leases are as follows:

2013

   $ 2,069  

2014

     1,195  

2015

     400  

2016

     35  

2017

     36  

Thereafter

     56  
       

Total minimum lease payments

     3,791  

Less amount representing interest

     (223 )
       

Present value of future minimum lease payments

     3,568  

Less current portion

     (1,892 )
       

Capital lease obligations, less current portion

   $ 1,676  
       
Schedule of future receipts under the leases

At December 31, 2012, future receipts under these leases are as follows:

2013

   $ 377  

2014

     377  

2015

     377  

2016

     377  

2017

     256  
       

Total

     1,767  

Less amount representing interest

     (193 )
       

 

   $ 1,574  
       

XML 49 R29.htm IDEA: XBRL DOCUMENT v2.4.0.6
Summary of Significant Accounting Policies(Policies)
 12 Months Ended
Dec. 31, 2012
Summary of Significant Accounting Policies  
Basis of Presentation

Basis of Presentation

        The 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 in accordance with U.S. generally accepted accounting principles ("US GAAP"). All intercompany accounts and transactions have been eliminated in consolidation.
Use of Estimates

Use of Estimates

        The preparation of consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements and revenues and expenses recorded during the reporting period. Actual results could differ from those estimates. Current economic conditions may require the use of additional estimates and these estimates may be subject to a greater degree of uncertainty as a result of the uncertain economy.
Cash and Cash Equivalents

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.
Fair Value of Financial Instruments

Fair Value of Financial Instruments

        The carrying values of the Company's financial instruments, including cash and cash equivalents, accounts and other receivables, notes receivable, accounts payable, accrued expenses and other current liabilities, capital lease obligations and notes payable approximate fair value.
Inventories

Inventories

        Inventories are stated at the lower of cost or market value on a first-in, first out basis. Management's estimate of market value includes a provision for slow-moving or obsolete inventory based upon inventory on hand and forecasted demand.

        Inventories consisted of the following as of December 31, 2011 and 2012:

 
   2011   2012  

Raw materials and spare parts

   $ 30,177   $ 30,137  

Work in process

     2,310     5,835  

Finished goods

     2,800     2,180  
           

Total

   $ 35,287   $ 38,152  
           
Property and Equipment

Property and Equipment

        Property and equipment are recorded at cost. Depreciation and amortization are recognized over the estimated useful lives of the assets using the straight-line method. The estimated useful lives of depreciable assets are twenty years for LNG liquefaction plant assets, ten years for station equipment and LNG trailers, and three to seven years for all other depreciable assets. Leasehold improvements are amortized over the shorter of their estimated useful lives or related lease terms. Periodically, the Company receives grant funding to assist in the financing of natural gas fueling station construction. The Company records the grant proceeds as a reduction of the cost of the respective asset. Total grant proceeds received were approximately $831, $3,090, and $5,908 for the years ended December 31, 2010, 2011 and 2012, respectively.
Long-Lived Assets

Long-Lived Assets

        The Company reviews long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying value of an asset may not be recoverable. Recoverability of long-lived assets to be held and used is measured by a comparison of the carrying amount of an asset to future net undiscounted cash flows expected to be generated by the asset or asset group. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. Assets to be disposed of are reported at the lower of the carrying amount or the fair value less costs to sell.

        During the fourth quarter of 2010, the Company's majority-owned subsidiary, Dallas Clean Energy, LLC ("DCE"), recorded an impairment charge of $717 related to equipment that was replaced as part of its expansion of the McCommas Bluff landfill in Dallas, Texas.
Goodwill and Intangible Assets

Goodwill and Intangible Assets

        Goodwill represents the excess of costs incurred over the fair value of the net assets of acquired businesses. Goodwill and intangible assets acquired in a business combination and determined to have an indefinite useful life are not amortized. In 2011, the Company changed its annual impairment testing to October 1 of each year. Beginning on October 1, 2011, the Company performed its test for Goodwill impairment under the amended guidance issued by the FASB in Accounting Standards Update ("ASU") 2011-08, Testing for Goodwill Impairment, issued in September 2011, which the Company chose to early adopt, effective October 1, 2011. Under the amended requirements of ASU 2011-08, an entity is not required to quantitatively determine a reporting unit's fair value, if it concludes, based upon a qualitative assessment, that it is not more likely than not that the reporting unit's fair value is less than its carrying amount. A qualitative assessment is an option available on an individual reporting unit basis and is an unconditional alternative to Step 1 of the goodwill impairment test. A reporting entity can choose to perform either Step 1 or a qualitative assessment in subsequent reporting periods. If the Company does conduct a Step 1 test, the Company looks at its projected future cash flows and its market capitalization for its respective operations. In these instances, to the extent the Company's projected future cash flows do not materialize as planned or its market capitalization decreases, the Company could be forced to take an impairment charge in future periods.

        Beginning on October 1, 2012, the Company performed its test for indefinite-lived intangible assets impairment under the amended guidance issued by the FASB in ASU 2012-02, Testing Indefinite-Lived Intangible Assets for Impairment, issued in July 2012, which the Company chose to early adopt, effective October 1, 2012. The amended requirements of ASU 2012-02 provided a similar framework for testing indefinite-lived intangible assets for impairment as the ASU 2011-08 does for testing goodwill for impairment.

        There were no impairment charges for goodwill or indefinite-lived intangible asset resulting from the October 1, 2011 or 2012 impairment testing, and no events have occurred subsequent to October 1, 2012 which indicates impairment may have occurred.

        Intangible assets with finite useful lives are amortized over their respective estimated useful lives using the straight-line method. The estimated useful lives of intangible assets with finite useful lives are two to 20 years for technology, one to 16 years for lease agreements, one to eight years for customer relationships, one to 10 years for acquired contracts, two to 20 years for trademarks and trade names, and three years for non-compete agreements. The intangible assets with finite useful lives are reviewed for impairment whenever events or changes in circumstances indicate that the carrying value of the asset may not be recoverable.

        During the fourth quarter of 2010, as a result of losing a competitive bid to a customer, the Company recorded an impairment charge of $1,531 related to an intangible asset. The Company's intangible assets as of December 31, 2011 and 2012 were as follows:

 
   2011   2012  

Technology

   $ 56,026   $ 57,595  

Lease agreements

     21,045     21,645  

Customer relationships

     21,590     23,334  

Acquired contracts

     13,075     13,075  

Trademark and tradenames

     7,400     7,400  

Non-compete agreements

     2,126     2,126  
           

Total intangible assets

     121,262     125,175  

Less accumulated amortization

     (19,757 )   (30,632 )

Foreign currency rate change

     598     4,739  
           

Net intangible assets

   $ 102,103   $ 99,282  
           

        Included above is a trademark of indefinite useful life with carrying value of $1,200 as of December 31, 2011 and 2012, respectively.

        Amortization expense for intangible assets was $5,915, $10,071, and $10,875 for the years ended December 31, 2010, 2011 and 2012, respectively. Estimated amortization expense for the five years succeeding the year ended December 31, 2012 is approximately $9,217, $8,838, $8,586, $8,504 and $7,733, respectively.
Warranty Liability

Warranty Liability

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

 
   December 31, 2011   December 31, 2012  

Warranty liability at beginning of year

   $ 2,338   $ 3,130  

Costs accrued for new warranty contracts and changes in estimates for pre-existing warranties

     3,208     3,733  

Service obligations honored

     (2,416 )   (4,198 )
           

Warranty liability at end of year

   $ 3,130   $ 2,665  
           
Asset Retirement Obligations

Asset Retirement Obligations

        The Company recognizes the fair value of a liability for an asset retirement obligation in the period in which the liability is incurred or becomes reasonably estimable and if there is a legal obligation to restore or remediate the property at the end of the asset life or at the end of the lease term. All of the Company's fueling and storage equipment is located above-ground. The liability amounts are based upon future retirement cost estimates and incorporate many assumptions such as the costs to restore the property, future inflation rates, and the adjusted risk free rate of interest. When the liability is initially recorded, the Company capitalizes the cost by increasing the related property and equipment balance. Over time, the liability is increased and expense is recognized for the change in the present value of the obligation, and the initial capitalized cost is depreciated over the useful life of the asset.

        The following table summarizes the activity of the asset retirement obligation, of which $964 and $1,215 is included in other long-term liabilities, with the remaining current portion included in accrued liabilities, as of December 31, 2011 and 2012, respectively:

 
   2011   2012  

Beginning balance

   $ 1,128   $ 1,179  

Liabilities incurred

     8     74  

Liabilities settled

     (3 )   —  

Accretion expense

     46     60  
           

Ending balance

   $ 1,179   $ 1,313  
           
Revenue Recognition

Revenue Recognition

        The Company recognizes revenue on gas sales and O&M services in accordance with US GAAP, which requires that four basic criteria must be met before revenue can be recognized: (i) persuasive evidence of an arrangement exists; (ii) delivery has occurred and title and the risks and rewards of ownership have been transferred to the customer or services have been rendered; (iii) the price is fixed or determinable; and (iv) collectability is reasonably assured. Applying these factors, the Company typically recognizes revenue from the sale of natural gas fuel at the time the fuel is dispensed or, in the case of LNG sales agreements, delivered to the customers' storage facilities. The Company recognizes revenue from O&M agreements as the related services are provided.

        In certain transactions with Clean Energy customers, the Company agrees to provide multiple products or services, including construction of a station, providing O&M to the station, and sale of fuel to the customer. The Company evaluates the separability of revenues based on FASB authoritative guidance, which provides a framework for establishing whether or not a particular arrangement with a customer has one or more revenue elements. In 2010, the Company elected to apply newly issued FASB authoritative guidance that allows it to use a combination of internal and external objective and reliable evidence to develop management's best estimate of the fair value of the contract elements. If the arrangement contains a lease, the Company uses the existing evidence of fair value to separate the lease from the other elements in the arrangement. The arrangement's consideration that is fixed or determinable is then allocated to each separate unit of accounting based on the estimated relative selling price of each deliverable, which is determined based on the historical data derived from the Company's stand alone projects. The revenue allocated to the construction of the station is recognized using the completed-contract method. The revenue allocated to the O&M and sale of fuel is recognized ratably over the term of the arrangement.

        The Company recognizes revenue related to its leasing activities in accordance with FASB authoritative guidance. The Company's existing station leases are sales-type leases, giving rise to profit at the delivery of the leased station. Unearned revenue is amortized into income over the life of the lease using the effective-interest method. For these arrangements, the Company recognizes gas sales and O&M service revenues as earned from the customer on a volume-delivered basis.

        The Company typically recognizes revenue on fueling station construction projects where it sells the station to the customer using the completed-contract method because the projects are short-term and the results of operations reported on the completed-contract basis would not vary materially from those resulting from the use of the percentage-of-completion method. The construction contract is considered to be substantially completed at the earlier of customer acceptance of the fueling station or the time when the fuel dispensing activities begin. When applicable, multi-station construction contracts are segmented into phases as negotiated with customers. Gross margin related to each phase is recognized at its substantial completion. IMW Industries, Ltd. ("IMW") and Wyoming Northstar Incorporated, Southstar, LLC, and M&S Rental LLC (collectively "Northstar") use the percentage-of-completion method of accounting to recognize revenue because their projects are small and they have been able to demonstrate that they can reasonably estimate costs to complete. In these circumstances, revenue is recognized based on costs incurred in relation to total estimated costs to be incurred for a project.

        The Company recognizes revenue on RNG sales and vehicle sales when it transfers title of the gas or vehicle to its customer.
Volumetric Excise Tax Credits (VETC)

Volumetric Excise Tax Credits ("VETC")

        The Company records its VETC credits as revenue as the credits are fully refundable and do not need to offset income tax liabilities to be received. VETC revenues for the years ended December 31, 2010 and 2011 were $16,042, and $17,889, respectively. During 2010, the legislation providing for VETC was reinstated in the fourth quarter of 2010 and made retroactive to January 1, 2010. The VETC legislation expired on December 31, 2011, but was made retroactive to January 1, 2012 and extended to December 31, 2013 in January 2013 (see note 19). Such credits for 2012 will be recognized in the first quarter of 2013.
LNG Transportation Costs

LNG Transportation Costs

        The Company records the costs incurred to transport LNG to its customers in the line item cost of sales in the accompanying statements of operations.
Advertising Costs

Advertising Costs

        Advertising costs are expensed as incurred. Advertising costs amounted to $1,260, $1,559, and $1,340 for the years ended December 31, 2010, 2011 and 2012, respectively.
Stock-based Compensation

Stock-based Compensation

        The Company recognizes compensation expense for all stock-based payment arrangements, net of an estimated forfeiture rate, over the requisite service period of the award. For stock options, the Company determines the grant date fair value using the Black-Scholes option-pricing model which requires the input of certain assumptions, including the expected life of the stock-based payment awards, stock price volatility and risk-free interest rates.
Foreign Currency Translation

Foreign Currency Translation

        In accordance with FASB authoritative guidance, the Company uses the local currency as the functional currency of its foreign subsidiary. Accordingly, all assets and liabilities outside the United States are translated into U.S. dollars at the rate of exchange in effect at the balance sheet date. Revenue and expense items are translated at the weighted-average exchange rates prevailing during the period. Net foreign currency translation adjustments are recorded as accumulated other comprehensive income (loss) in stockholders' equity.

        Foreign currency transactions occur when there is a transaction denominated in other than the respective entity's functional currency. The Company records the changes in the exchange rate for these transactions in the consolidated statements of operations. For the fiscal years ended December 31, 2010, 2011 and 2012, foreign exchange transaction gains and (losses) were included in other income (expense) and were $1,902, $(596), and $678, respectively.
Income Taxes

Income Taxes

        Income taxes are computed using the asset and liability method. Under this method, deferred income taxes are recognized by applying enacted statutory tax rates applicable to future years to differences between the tax bases and financial reporting amounts of existing assets and liabilities. Valuation allowances are established when it is more likely than not that such deferred tax assets will not be realized.

        The Company has a recognition threshold and a measurement attribute for the financial statement recognition and measurement of tax positions taken or expected to be taken in a tax return. For those benefits to be recognized, a tax position must be more likely than not to be sustained upon examination by taxing authorities based on the technical merits of the position. The amount recognized is measured as the largest amount of benefit that has a greater than 50 percent likelihood of being realized upon ultimate settlement. The Company recognizes potential accrued interest and penalties related to unrecognized tax benefit in income tax expense.
Net Loss Per Share

Net Loss Per Share

        Basic net loss per share is computed by dividing net loss attributable to Clean Energy by the weighted-average number of common shares and common shares issuable for little or no cash consideration outstanding during the period. Diluted net loss per share is computed by dividing net loss attributable to Clean Energy by the weighted-average number of common shares and common shares issuable for little or no cash consideration outstanding and potentially dilutive securities outstanding during the period. Potentially dilutive securities include stock options and warrants, in 2011 and 2012, convertible notes, and in 2012, restricted stock units. The dilutive effect of stock options and warrants is computed under the treasury stock method. Potentially dilutive securities are excluded from the computations of diluted net loss per share if their effect would be antidilutive. In 2012, 5,000,000 shares of common stock related to the GE Warrant were included in the basic and dilutive net loss per share calculation.

        The following potentially dilutive securities have been excluded from the diluted net loss per share calculations because their effect would have been antidilutive:

 
   2010   2011   2012  

Stock options

     10,433,551     10,683,303     12,083,677  

Warrants

     17,130,682     2,130,682     2,130,682  

Convertibles notes

     —     13,164,557     16,262,226  

Restricted stock units

     —     —     1,545,000  
Derivative Financial Instruments

Derivative Financial Instruments

        The Company, in an effort to manage its natural gas commodity price risk exposures related to certain contracts, utilizes derivative financial instruments. The Company, from time to time, enters into natural gas futures contracts that are over-the-counter swap transactions that convert its index-based gas supply arrangements to fixed price arrangements. The Company accounts for its derivative instruments in accordance with FASB authoritative guidance for derivative instruments and hedging activities, which requires the recognition of all derivatives as either assets or liabilities in the consolidated balance sheet and the measurement of those instruments at fair value.

        The Company's futures contracts at December 31, 2012 are being accounted for as cash flow hedges and are being used to mitigate the Company's exposure to changes in the price of natural gas and not for speculative purposes. At December 31, 2012, all of the Company's futures contracts qualified for hedge accounting.

        The counter-party to the Company's derivative transactions is a high credit quality counterparty; however, the Company is subject to counterparty credit risk to the extent the counterparty to the derivatives is unable to meet its settlement commitments. The Company manages this credit risk by minimizing the number and size of its derivative contracts. The Company actively monitors the creditworthiness of its counterparties and records valuation adjustments against the derivative assets to reflect counterparty risk, if necessary. The counter-party is also exposed to credit risk of the Company, which requires the Company to provide cash deposits as collateral.
Comprehensive Income (Loss)

Comprehensive Income (Loss)

        Comprehensive income (loss) is defined as the change in equity (net assets) of a business enterprise during the period from transactions and other events and circumstances from non-owner sources. The difference between net income and comprehensive income for the years ended December 31, 2010, 2011, and 2012 was primarily comprised of the Company's foreign currency translation adjustments and unrealized gains (losses) on futures contracts.
Concentration of Credit Risk

Concentration of Credit Risk

        Credit is extended to all customers based on financial condition, and collateral is generally not required. Concentrations of credit risk with respect to trade receivables are limited because of the large number of customers comprising the Company's customer base and dispersion across many different industries and geographies. However, certain international customers have historically been slower to pay on trade receivables. Accordingly, the Company continuously monitors collections and payments from its customers and maintains a provision for estimated credit losses based upon its historical experience and any specific customer collection issues that it has identified. In addition, through Export Development Canada, IMW maintains accounts receivable insurance on a substantial portion of its foreign trade receivables, which covers up to 90% of the related outstanding balance. Although such credit losses have historically been within the Company's expectations and the provisions established, the Company cannot guarantee that it will continue to experience the same credit loss rates that it has in the past.
Recently Adopted Accounting Changes and Recently Issued and Adopted Accounting Standards

Recently Adopted Accounting Changes and Recently Issued and Adopted Accounting Standards

        On January 1, 2012, the Company adopted changes issued by the FASB to conform existing guidance regarding fair value measurement and disclosure between GAAP and International Financial Reporting Standards. These changes both clarify the FASB's intent about the application of existing fair value measurement and disclosure requirements and amend certain principles or requirements for measuring fair value or for disclosing information about fair value measurements. The clarifying changes relate to the application of the highest and best use and valuation premise concepts, measuring the fair value of an instrument classified in a reporting entity's shareholders' equity, and disclosure of quantitative information about unobservable inputs used for Level 3 fair value measurements. The amendments relate to measuring the fair value of financial instruments that are managed within a portfolio, application of premiums and discounts in a fair value measurement, and additional disclosures concerning the valuation processes used and sensitivity of the fair value measurement to changes in unobservable inputs for those items categorized as Level 3, a reporting entity's use of a nonfinancial asset in a way that differs from the asset's highest and best use, and the categorization by level in the fair value hierarchy for items required to be measured at fair value for disclosure purposes only. Other than the additional disclosure requirements (see note 18), the adoption of these changes had no impact on the consolidated financial statements.

        On January 1, 2012, the Company adopted changes issued by the FASB to the presentation of comprehensive income. These changes give an entity the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. The option to present components of other comprehensive income as part of the statement of changes in stockholders' equity was eliminated. The items that must be reported in other comprehensive income or when an item of other comprehensive income must be reclassified to net income were not changed. Additionally, no changes were made to the calculation and presentation of earnings per share. Management elected to present the two-statement option. Other than the change in presentation, the adoption of these changes had no impact on the consolidated financial statements.

        On October 1, 2012, the Company early adopted ASU 2012-02, Intangibles—Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment. The update simplifies the guidance for testing the decline in the realizable value (impairment) of indefinite-lived intangible assets other than goodwill. The new guidance allows an entity the option to first assess qualitative factors to determine whether it is necessary to perform the quantitative impairment test. An entity electing to perform a qualitative assessment is no longer required to calculate the fair value of an indefinite-lived intangible asset unless the entity determines, based on a qualitative assessment, that it is more likely than not that the asset is impaired. The adoption of these changes had no impact on the consolidated financial statements.

        On October 1, 2012, the FASB issued ASU 2012-04, Technical Corrections and Improvements. The amendments represent changes to clarify the Accounting Standards Codification (ASC), correct unintended application of guidance, or make minor improvements to the ASC that are not expected to have a significant effect on current accounting practice. The Company does not expect the adoption of these changes to have a material impact on its consolidated financial statements.
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Schedule II: Valuation and Qualifying Accounts
 12 Months Ended
Dec. 31, 2012
Schedule II: Valuation and Qualifying Accounts  
Schedule II: Valuation and Qualifying Accounts

 

 

 
   Allowances for Doubtful Trade Receivables   Allowance for Doubtful Notes Receivables  

Balance at December 31, 2009

   $ 898   $ 216  

Charges (benefit) to operations

     264     —  

Deductions

     (460 )   (123 )
           

Balance at December 31, 2010

     702     93  

Charges (benefit) to operations

     344     —  

Deductions

     (334 )   (73 )
           

Balance at December 31, 2011

     712     20  

Charges (benefit) to operations

     434     924  

Deductions

     (242 )   (35 )
           

Balance at December 31, 2012

   $ 904   $ 909  
           

        
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Other Receivables (Details) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2012
Dec. 31, 2011
Other Receivables    
Other receivables $ 17,808 $ 19,601
Loans to customers to finance vehicle purchases
    
Other Receivables    
Other receivables 4,151 1,789
Capital lease receivables
    
Other Receivables    
Other receivables 308 310
Accrued customer billings
    
Other Receivables    
Other receivables 6,934 5,860
Fuel tax credits
    
Other Receivables    
Other receivables 2,780 5,912
Other
    
Other Receivables    
Other receivables $ 3,635 $ 5,730
XML 52 R44.htm IDEA: XBRL DOCUMENT v2.4.0.6
Fair Value Measurements (Tables)
 12 Months Ended
Dec. 31, 2012
Fair Value Measurements  
Schedule of information by level for assets and liabilities that are measured at fair value on a recurring basis

 

 

Description
  Balance at
December 31, 2011		   Level 1   Level 2   Level 3  

Assets:

                          

Available-for-sale securities(1):

                          

Certificate of deposits

   $ 10,000   $ —   $ 10,000   $ —  

Municipal bonds and notes

     19,589     —     19,589     —  

Zero coupon bonds

     712     —     712     —  

Corporate bonds

     3,028     —     3,028     —  

Liabilities:

                          

Natural gas futures contracts(2)

     2,335     —     2,335     —  

Contingent consideration obligation(3)

     5,978     —     —     5,978  

Series I warrants(4)

     11,493     —     —     11,493  


 

Description
  Balance at
December 31, 2012		   Level 1   Level 2   Level 3  

Assets:

                          

Available-for-sale securities(1):

                          

Certificate of deposits

   $ 10,021   $ —   $ 10,021   $ —  

Municipal bonds and notes

     23,650     —     23,650     —  

Corporate bonds

     4,504     —     4,504     —  

Liabilities:

                          

Natural gas futures contracts(2)

     107     —     107     —  

Contingent consideration obligation(3)

     1,516     —     —     1,516  

Series I warrants(4)

     8,102     —     —     8,102  
(1)
Included in short-term investments in the consolidated balance sheets. See note 4 for further information.

(2)
See note 10 for further information.

(3)
The current portion is included in accrued liabilities, and the long-term portion is included in other long-term liabilities in the consolidated balance sheets.

(4)
Included in other long-term liabilities in the consolidated balance sheets.

        
Reconciliation of the beginning and ending balances of items measured at fair value on a recurring basis that used significant unobservable inputs (Level 3)

 

 

Liabilities: Contingent Consideration
  2011   2012  

Beginning Balance

   $ 11,200   $ 5,978  

Business combinations

     —     —  

Total (gain) loss included in earnings

     (2,828 )   (4,112 )

Payments

     (2,394 )   (350 )

Transfers In/Out

     —     —  
           

Ending Balance

   $ 5,978   $ 1,516  
           


 

Liabilities: Series I Warrants
  2011   2012  

Beginning Balance

   $ 14,148   $ 11,493  

Total (gain) loss included in earnings

     (2,655 )   (3,391 )

Issuance of warrants

     —     —  

Exercise of warrants

     —     —  

Transfers In/Out

     —     —  
           

Ending Balance

   $ 11,493   $ 8,102  
           

        
Level 3 | Contingent consideration obligation
  
Valuation processes for Level 3 Fair Value Measurements  
Schedule of fair value measurements of liabilities which fall within level 3 of the fair value hierarchy

The Company estimated the fair value of the contingent consideration using a discounted cash flow model that considers the payout structure based on the following inputs as of December 31, 2012:

Unobservable Input
  Range or Weighted Average

Gross profit projection

   $14,162–$32,641

Probability of reaching target gross profit

   0.0%–75.0%

Volatility of gross profit (peer group)

   14.6%–55.2% (simple average 31.4%)

Risk adjusted discount rate

   35.9%
Level 3 | Series I Warrant
  
Valuation processes for Level 3 Fair Value Measurements  
Schedule of fair value measurements of liabilities which fall within level 3 of the fair value hierarchy

The Company estimated the fair value of its Series I warrant liability using the Black-Scholes Model based on the following inputs as of December 31, 2012:

Unobservable Input
  Range or Weighted Average  

Current market price of the Company's common stock

     $12.45  

Exercise price of the warrant

     $12.68  

Dividend yield

     0.00%  

Remaining term of the warrant

     3.33  

Implied volatility of the Company's common stock

     45.2%–47.2%  

Assumed discount rate

     Simple average 0.4%  
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Summary of Significant Accounting Policies (Tables)
 12 Months Ended
Dec. 31, 2012
Summary of Significant Accounting Policies  
Schedule of inventories

 

 

 
   2011   2012  

Raw materials and spare parts

   $ 30,177   $ 30,137  

Work in process

     2,310     5,835  

Finished goods

     2,800     2,180  
           

Total

   $ 35,287   $ 38,152  
           
Schedule of the company's intangible assets

 

 

 
   2011   2012  

Technology

   $ 56,026   $ 57,595  

Lease agreements

     21,045     21,645  

Customer relationships

     21,590     23,334  

Acquired contracts

     13,075     13,075  

Trademark and tradenames

     7,400     7,400  

Non-compete agreements

     2,126     2,126  
           

Total intangible assets

     121,262     125,175  

Less accumulated amortization

     (19,757 )   (30,632 )

Foreign currency rate change

     598     4,739  
           

Net intangible assets

   $ 102,103   $ 99,282  
           

        
Schedule of changes in the warranty liability

 

 

 
   December 31, 2011   December 31, 2012  

Warranty liability at beginning of year

   $ 2,338   $ 3,130  

Costs accrued for new warranty contracts and changes in estimates for pre-existing warranties

     3,208     3,733  

Service obligations honored

     (2,416 )   (4,198 )
           

Warranty liability at end of year

   $ 3,130   $ 2,665  
           
Summary of activity of the asset retirement obligation

 

 

 
   2011   2012  

Beginning balance

   $ 1,128   $ 1,179  

Liabilities incurred

     8     74  

Liabilities settled

     (3 )   —  

Accretion expense

     46     60  
           

Ending balance

   $ 1,179   $ 1,313  
           
Schedule of potentially dilutive securities that have been excluded from the diluted net loss per share calculations because their effect would have been antidilutive

 

 

 
   2010   2011   2012  

Stock options

     10,433,551     10,683,303     12,083,677  

Warrants

     17,130,682     2,130,682     2,130,682  

Convertibles notes

     —     13,164,557     16,262,226  

Restricted stock units

     —     —     1,545,000  
XML 54 R31.htm IDEA: XBRL DOCUMENT v2.4.0.6
Acquisitions (Tables)
 12 Months Ended
Dec. 31, 2012
IMW
  
Acquisitions  
Summary of allocation of the aggregate purchase price to the estimated fair value of the assets acquired and liabilities assumed as of the acquisition date

 

 

Current assets

   $ 27,149  

Property, plant and equipment

     2,559  

Identifiable intangible assets

     81,400  

Goodwill

     45,049  
       

Total assets acquired

     156,157  

Liabilities assumed

     (25,986 )
       

Total purchase price

   $ 130,171  
       

        
Schedule of Company's unaudited pro forma results of operations as if the acquisition had occurred at on January 1, 2010

 

 

 
   For the year ended
December 31, 2010		  

Revenue

   $ 249,093  

Net (loss)

     (7,922 )

(Loss) per share:

        

Basic and diluted

   $ (0.12 )

        
Northstar
  
Acquisitions  
Summary of allocation of the aggregate purchase price to the estimated fair value of the assets acquired and liabilities assumed as of the acquisition date

The following table summarizes the estimated fair values of the assets acquired and liabilities assumed as of December 15, 2010:

Current assets

   $ 4,434  

Property, plant and equipment

     941  

Identifiable intangible assets

     3,350  

Goodwill

     5,228  
       

Total assets acquired

     13,953  

Liabilities assumed

     (3,648 )
       

Total purchase price

   $ 10,305  
       
ServoTech
  
Acquisitions  
Summary of allocation of the aggregate purchase price to the estimated fair value of the assets acquired and liabilities assumed as of the acquisition date

 

 

Current assets

   $ 2,655  

Property & equipment

     239  

Identifiable intangible assets

     3,913  
       

Total assets acquired

     6,807  

Current liabilities assumed

     (2,807 )
       

Total purchase price

   $ 4,000  
       

        
XML 55 R8.htm IDEA: XBRL DOCUMENT v2.4.0.6
Consolidated Statements of Cash Flows (Parenthetical) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Consolidated Statements of Cash Flows      
Interest paid, capitalized $ 6,304 $ 1,352 $ 434
XML 56 R32.htm IDEA: XBRL DOCUMENT v2.4.0.6
Restricted Cash (Tables)
 12 Months Ended
Dec. 31, 2012
Restricted Cash  
Schedule of components of restricted cash

 

 

 
   December 31, 2011   December 31, 2012  

Short-term restricted cash

              

Standby letters of credit

   $ 1,237   $ 669  

DCEMB bonds—current operating costs

     3,555     7,776  
           

Total short-term restricted cash

     4,792     8,445  

Chesapeake loan

     40,322     12,256  

DCEMB bonds—long-term plant expansion

     14,482     952  
           

Total restricted cash

   $ 59,596   $ 21,653  
           
XML 57 R40.htm IDEA: XBRL DOCUMENT v2.4.0.6
Income Taxes (Tables)
 12 Months Ended
Dec. 31, 2012
Income Taxes  
Schedule of components of income (loss) before income taxes

 

 

 
   2010   2011   2012  

U.S. 

   $ (6,048 ) $ (30,002 ) $ (91,608 )

Foreign

     1,839     (18,156 )   (7,960 )
               

 

   $ (4,209 ) $ (48,158 ) $ (99,568 )
               

        
Schedule of provision (benefit) for income taxes

 

 

 
   2010   2011   2012  

Current:

                    

Federal

   $ (1,753 ) $ 206   $ 269  

State

     255     296     302  

Foreign

     117     396     (61 )
               

Total current

     (1,381 )   898     510  

Deferred:

                    

Federal

     (4,361 )   (8,012 )   (20,646 )

State

     (966 )   (1,724 )   (3,445 )

Foreign

     145     (4,075 )   (3,053 )

Change in valuation allowance

     5,127     12,210     27,928  
               

Total deferred

     (55 )   (1,601 )   784  
               

Total

   $ (1,436 ) $ (703 ) $ 1,294  
               

        
Schedule of reconciliation of federal income tax rate to the actual effective tax rate

 

 

 
   2010   2011   2012  

Computed expected tax expense (benefit)

   $ (1,473 ) $ (16,855 ) $ (34,849 )

State and local taxes, net of federal benefit

     174     202     121  

Nondeductible expenses

     (2,615 )   3,073     5,194  

Tax rate differential on foreign earnings

     (580 )   5,273     (717 )

Refund of alternative minimum taxes

     (1,323 )   —     —  

Tax credits

     (875 )   (834 )   —  

Other

     129     (148 )   (1,563 )

Change in valuation allowance

     5,127     8,586     33,108  
               

Total tax expense (benefit)

   $ (1,436 ) $ (703 ) $ 1,294  
               

        
Schedule of tax effect of temporary differences that give rise to deferred tax assets and liabilities

 

 

 
   2011   2012  

Deferred tax assets:

              

Accrued expenses

   $ 1,163   $ 2,303  

Sales-type leases

     212     500  

Alternative minimum tax and general business credits

     3,470     3,297  

Derivative loss

     2,363     1,831  

Stock option expense

     11,611     15,259  

Other

     1,223     644  

Loss carryforwards

     55,212     79,819  
           

Total deferred tax assets

     75,254     103,653  

Less valuation allowance

     (53,329 )   (81,257 )
           

Net deferred tax assets

     21,925     22,396  
           

Deferred tax liabilities:

              

Depreciation and amortization—domestic

     (19,724 )   (20,291 )

Depreciation and amortization—foreign

     (928 )   (1,045 )

Partnership income

     (1,500 )   (2,071 )
           

Total deferred tax liabilities

     (22,152 )   (23,407 )
           

Net deferred tax assets (liabilities)

   $ (227 ) $ (1,011 )
           

        
Schedule of reconciliation of the total amounts of unrecognized tax benefits

 

 

Unrecognized tax benefit—December 31, 2010

   $ 50  

Gross increases—tax positions in prior years

     255  

Gross (decreases)—tax positions in prior years

     —  
       

Unrecognized tax benefit—December 31, 2011

     305  

Gross increases—tax positions in prior years

     260  

Gross (decreases)—tax positions in prior years

     (50 )
       

Unrecognized tax benefit—December 31, 2012

   $ 515  
       

        
XML 58 R53.htm IDEA: XBRL DOCUMENT v2.4.0.6
Acquisitions (Details 3) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended 0 Months Ended 0 Months Ended
Dec. 31, 2012
Apr. 30, 2012
ServoTech
Feb. 25, 2011
ServoTech
Oct. 31, 2012
ServoTech
Apr. 30, 2012
ServoTech
Minimum
Apr. 30, 2012
ServoTech
Maximum
Acquisitions            
Cash payment   $ 1,400 $ 1,200 $ 1,400    
Ownership interest acquired (as a percent)     19.90%      
Remaining interest for which the entity has an option to purchase (as a percent)     80.10%      
Exercise price     2,800      
Period during which remaining interest may be acquired     15 months      
Percentage of amount to be paid to purchase remaining interest 50.00% 50.00%        
Allocation of aggregate purchase price            
Current assets   2,655        
Property, plant and equipment   239        
Identifiable intangible assets   3,913        
Total assets acquired   6,807        
Current liabilities assumed   (2,807)        
Total purchase price   $ 4,000        
Identifiable intangible assets, estimated useful lives         2 years 7 years
XML 59 R72.htm IDEA: XBRL DOCUMENT v2.4.0.6
Geographic Information (Details) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Geographic Information      
Total revenue $ 334,008 $ 292,717 $ 211,834
Total operating income (loss) (70,522) (38,568) (5,522)
Total long-lived assets 605,905 449,766 397,910
United States
      
Geographic Information      
Total revenue 286,125 248,419 194,512
Total operating income (loss) (69,030) (33,761) (7,251)
Total long-lived assets 480,067 325,386 262,545
Canada
      
Geographic Information      
Total revenue 8,364 4,800 6,158
Total operating income (loss) (188) (5,844) 1,386
Total long-lived assets 122,291 121,103 133,078
Other
      
Geographic Information      
Total revenue 39,519 39,498 11,164
Total operating income (loss) (1,304) 1,037 343
Total long-lived assets $ 3,547 $ 3,277 $ 2,287
XML 60 R2.htm IDEA: XBRL DOCUMENT v2.4.0.6
Consolidated Balance Sheets (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2012
Dec. 31, 2011
Current assets:    
Cash and cash equivalents $ 108,522 $ 238,125
Restricted cash 8,445 4,792
Short-term investments 38,175 33,329
Accounts receivable, net of allowance for doubtful accounts of $712 and $905 as of December 31, 2011 and December 31, 2012, respectively 57,594 56,455
Other receivables 17,808 19,601
Inventory, net 38,152 35,287
Prepaid expenses and other current assets 16,002 22,252
Total current assets 284,698 409,841
Land, property and equipment, net 428,177 257,463
Restricted cash 13,208 54,804
Notes receivable and other long-term assets 71,389 16,650
Investments in other entities 2,581 16,459
Goodwill 75,865 73,741
Intangible assets, net 99,282 102,103
Total assets 975,200 931,061
Current liabilities:    
Current portion of long-term debt and capital lease obligations 30,389 22,925
Accounts payable 39,216 36,668
Accrued liabilities 30,794 28,255
Deferred revenue 13,521 9,621
Total current liabilities 113,920 97,469
Long-term debt and capital lease obligations, less current portion 300,636 266,497
Other long-term liabilities 14,014 22,687
Total liabilities 428,570 386,653
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 149,000,000 shares; issued and outstanding 85,433,258 shares and 87,634,478 shares at December 31, 2011 and December 31, 2012, respectively 9 9
Additional paid-in capital 837,367 741,650
Accumulated deficit (300,814) (199,559)
Accumulated other comprehensive loss 6,151 (1,216)
Total Clean Energy Fuels Corp. stockholders' equity 542,713 540,884
Noncontrolling interest in subsidiary 3,917 3,524
Total stockholders' equity 546,630 544,408
Total liabilities and stockholders' equity $ 975,200 $ 931,061
XML 61 R45.htm IDEA: XBRL DOCUMENT v2.4.0.6
Summary of Significant Accounting Policies (Details) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
item
Dec. 31, 2011
Dec. 31, 2010
Summary of Significant Accounting Policies      
Number of natural gas fueling locations 348    
Number of states where the natural gas stations are located 32    
Inventories      
Raw materials and spare parts $ 30,137 $ 30,177  
Work in process 5,835 2,310  
Finished goods 2,180 2,800  
Total 38,152 35,287  
Property and Equipment      
Proceeds from grants $ 5,908 $ 3,090 $ 831
LNG liquefaction plants
      
Property and Equipment      
Estimated useful lives 20 years    
Station equipment
      
Property and Equipment      
Estimated useful lives 10 years    
LNG trailers
      
Property and Equipment      
Estimated useful lives 10 years    
Other equipment | Minimum
      
Property and Equipment      
Estimated useful lives 3 years    
Other equipment | Maximum
      
Property and Equipment      
Estimated useful lives 7 years    
XML 62 R6.htm IDEA: XBRL DOCUMENT v2.4.0.6
Consolidated Statements of Stockholders' Equity (USD $)
In Thousands, except Share data, unless otherwise specified
Total
Common stock
Additional Paid-In Capital
Retained Earnings (Accumulated Deficit)
Accumulated Other Comprehensive Income (Loss)
Noncontrolling Interest in Subsidiary
Balance at Dec. 31, 2009 $ 280,376 $ 6 $ 424,581 $ (149,410) $ 2,013 $ 3,186
Balance (in shares) at Dec. 31, 2009   59,840,151        
Increase (Decrease) in Stockholders' Equity            
Issuance of common stock upon exercise of options 11,049   11,049      
Issuance of common stock upon exercise of options (in shares)   1,118,827        
Issuance of common stock, net of offering costs 42,562   42,562      
Issuance of common stock, net of offering costs (in shares)   3,450,000        
Issuance of common stock upon exercise of Series I warrants 17,152   17,152      
Issuance of common stock upon exercise of Series I warrants (in shares)   1,183,712        
Issuance of common stock upon business combinations 61,939 1 61,938      
Issuance of common stock upon business combinations (in shares)   4,017,408        
Stock-based compensation 11,920   11,920      
Net loss (2,773)     (2,516)   (257)
Unrealized gain (loss) on futures contracts (4,231)       (4,231)  
Foreign currency translation adjustment (1,778)       (1,778)  
Balance at Dec. 31, 2010 416,216 7 569,202 (151,926) (3,996) 2,929
Balance (in shares) at Dec. 31, 2010   69,610,098        
Increase (Decrease) in Stockholders' Equity            
Issuance of common stock upon exercise of options 1,477   1,477      
Issuance of common stock upon exercise of options (in shares)   221,234        
Issuance of common stock, net of offering costs 7,500   7,500      
Issuance of common stock, net of offering costs (in shares)   601,926        
Issuance of common stock upon exercise of Boone Pickens warrants 150,000 2 149,998      
Issuance of common stock upon exercise of Boone Pickens warrants (in shares)   15,000,000        
Stock-based compensation 13,473   13,473      
Non-controlling interest contribution 417         417
Net loss (47,455)     (47,633)   178
Unrealized gain (loss) on futures contracts 2,091       2,091  
Unrealized loss on short-term investments available for sale (126)       (126)  
Foreign currency translation adjustment 815       815  
Balance at Dec. 31, 2011 544,408 9 741,650 (199,559) (1,216) 3,524
Balance (in shares) at Dec. 31, 2011 85,433,258 85,433,258        
Increase (Decrease) in Stockholders' Equity            
Issuance of common stock upon exercise of options 8,969   8,969      
Issuance of common stock upon exercise of options (in shares)   1,568,480        
Issuance of common stock, net of offering costs 8,503   8,503      
Issuance of common stock, net of offering costs (in shares)   632,740        
Issuance of warrants in connection with the GE Credit Agreement 56,158   56,158      
Stock-based compensation 22,087   22,087      
Net loss (100,862)     (101,255)   393
Unrealized gain (loss) on futures contracts 2,151       2,151  
Unrealized loss on short-term investments available for sale (32)       (32)  
Foreign currency translation adjustment 5,248       5,248  
Balance at Dec. 31, 2012 $ 546,630 $ 9 $ 837,367 $ (300,814) $ 6,151 $ 3,917
Balance (in shares) at Dec. 31, 2012 87,634,478 87,634,478        
XML 63 R59.htm IDEA: XBRL DOCUMENT v2.4.0.6
Investment in Other Entities (Details 2) (Peru JV, USD $)
In Thousands, unless otherwise specified
Dec. 31, 2012
Peru JV
  
Equity method investments  
Investment amount $ 2,581
XML 64 R35.htm IDEA: XBRL DOCUMENT v2.4.0.6
Land, Property and Equipment (Tables)
 12 Months Ended
Dec. 31, 2012
Land, Property and Equipment  
Summary of land, property and equipment

 

 

 
   2011   2012  

Land

   $ 1,198   $ 1,476  

LNG liquefaction plants

     93,109     93,384  

RNG plants

     21,005     23,582  

Station equipment

     118,613     158,447  

LNG trailers

     13,532     13,566  

Other equipment

     26,508     47,143  

Construction in progress

     66,256     198,916  
           

 

     340,221     536,514  

Less accumulated depreciation

     (82,758 )   (108,337 )
           

 

   $ 257,463   $ 428,177  
           

        
XML 65 R65.htm IDEA: XBRL DOCUMENT v2.4.0.6
Stockholders' Equity (Details) (USD $)
In Thousands, except Share data, unless otherwise specified
 0 Months Ended 12 Months Ended 0 Months Ended 0 Months Ended 0 Months Ended 0 Months Ended
Nov. 03, 2008
Dec. 31, 2012
item
Dec. 31, 2011
Oct. 28, 2008
Nov. 03, 2008
Series I Warrant
Oct. 28, 2008
Series I Warrant
Nov. 12, 2008
Series II Warrant
Nov. 03, 2008
Series II Warrant
Oct. 28, 2008
Series II Warrant
Nov. 10, 2010
Amended Series I Warrant
item
Nov. 07, 2012
GE Warrant
GE Credit Agreement
Nov. 07, 2012
GE Warrant
Tranche A Loans
Nov. 07, 2012
GE Warrant
Tranche B Loans
Dec. 28, 2006
Boone Pickens
Nov. 11, 2010
Common stock
Nov. 03, 2008
Common stock
Oct. 28, 2008
Common stock
Nov. 07, 2012
Common stock
GE Warrant
GE Credit Agreement
Maximum
Nov. 11, 2010
Common stock
Key executives
Stockholders' Equity                                      
Authorized number of classes of capital stock   2                                  
Preferred stock, par value (in dollars per share)   $ 0.0001 $ 0.0001                                
Authorized shares   150,000,000                                  
Common stock, Authorized shares   149,000,000 149,000,000                                
Preferred stock, Authorized shares   1,000,000 1,000,000                                
Number of votes per share held by holders of common stock   1                                  
Stockholders' Equity                                      
Number of shares issued                             3,450,000       50,068
Common stock price per share (in dollars per share)                             $ 13.25       $ 14.48
Number of shares issued to underwriter upon exercise of options                             450,000        
Aggregate net proceeds from issuance of shares after deducting underwriting discounts and commissions and offering expenses                             $ 42,562        
Number of units authorized under the Placement Agent Agreement       4,419,192                              
Number of shares of the company's common stock in a unit                 1               1    
Number of shares that can be purchased upon exercise of each warrant           0.75     0.2571 1,183,712       15,000,000       5,000,000  
Number of shares that can be purchased upon exercise of warrants         3,314,394     1,136,364                      
Common stock, Par value (in dollars per share)   $ 0.0001 $ 0.0001               $ 0.0001           $ 0.0001    
Unit price (in dollars per unit)       $ 7.92                              
Number of shares issued for units under Placement Agent Agreement                               4,419,192      
Proceeds after deducting the placement agent's fees and other offering expenses related to the sale of units 32,484       9,745     3,573               19,166      
Period from which warrants are exercisable         6 months                            
Expiration term         7 years                 5 years          
Exercise price (in dollars per share)         $ 12.68   $ 0.01       $ 0.01     $ 10.00          
Number of holders of warrants entering into amendment with the company                   1                  
Amount paid to holders on modification of term                   3,172                  
Total number of warrants exercised (in shares)             1,134,759     1,183,712                  
Total value of warrants exercised                   15,009                  
Gain on exercise of warrants                   3,208                  
Number of shares immediately exercisable                     500,000                
Number of shares that will become exercisable at the time the specified loan is made under the credit agreement                     4,500,000 1,250,000 1,250,000            
Number of additional shares that will become exercisable at the time that specified loan of at least $15,000,000 principal amount is made under the credit agreement                       1,000,000 1,000,000            
Minimum specified principal amount for additional shares to become exercisable                       15,000 15,000            
Additional number of shares that will be exercisable if no loans are made                     500,000                
Percentage of market price below which stock sale is a "Dilutive Issuance"                     80.00%                
Fair value of warrants issued, additional paid-in capital   $ 56,158                 $ 56,158                
XML 66 R22.htm IDEA: XBRL DOCUMENT v2.4.0.6
Geographic Information
 12 Months Ended
Dec. 31, 2012
Geographic Information  
Geographic Information

(14) Geographic Information

        Several of the Company's functions, including marketing, engineering, and finance are performed at the corporate level. As a result, significant interdependence and overlap exists among the Company's geographic areas. Accordingly, revenue, operating income (loss), and long-lived assets shown for each geographic area may not be the amounts which would have been reported if the geographic areas were independent of one another. Revenue by geographic area is based on where services are rendered and finished goods are sold. Operation income (loss) is based on the location of the entity selling the finished goods or providing the services.

 
   2010   2011   2012  

Revenue:

                    

United States

   $ 194,512   $ 248,419   $ 286,125  

Canada

     6,158     4,800     8,364  

Other

     11,164     39,498     39,519  
               

Total revenue

   $ 211,834   $ 292,717   $ 334,008  
               

Operating income (loss):

                    

United States

   $ (7,251 ) $ (33,761 ) $ (69,030 )

Canada

     1,386     (5,844 )   (188 )

Other

     343     1,037     (1,304 )
               

Total operating income (loss)

   $ (5,522 ) $ (38,568 ) $ (70,522 )
               

Long-lived assets:

                    

United States

   $ 262,545   $ 325,386   $ 480,067  

Canada

     133,078     121,103     122,291  

Other

     2,287     3,277     3,547  
               

Total long-lived assets

   $ 397,910   $ 449,766   $ 605,905  
               

        The Company's goodwill and intangible assets at December 31, 2010, 2011 and 2012 relate to its United States operations, its BAF operations, IMW operations, and Northstar operations.
XML 67 R36.htm IDEA: XBRL DOCUMENT v2.4.0.6
Accrued Liabilities (Tables)
 12 Months Ended
Dec. 31, 2012
Accrued Liabilities  
Schedule of accrued liabilities

 

 

 
   2011   2012  

Salaries and wages

   $ 5,088   $ 4,558  

Accrued gas and equipment purchases

     4,773     10,091  

Derivative liability

     2,259     112  

Contingent consideration obligations

     378     70  

Accrued property and other taxes

     3,043     4,483  

Accrued professional fees

     875     1,310  

Accrued employee benefits

     1,431     2,607  

Accrued warranty liability

     3,130     2,665  

Other

     7,278     4,898  
           

 

   $ 28,255   $ 30,794  
           
XML 68 R24.htm IDEA: XBRL DOCUMENT v2.4.0.6
Supplier Concentrations
 12 Months Ended
Dec. 31, 2012
Supplier Concentrations  
Supplier Concentrations

(16) Supplier Concentrations

        During 2010, 2011, and 2012, the Company incurred approximately 9%, 9%, and 8%, respectively, of its natural gas expense related to its LNG sales from Williams Gas Processing Company pursuant to a floating rate purchase contract that includes minimum purchase commitments. During 2010, 2011, and 2012, the Company incurred approximately 31%, 30% and 31%, respectively, of its natural gas expense related to its LNG sales from Shell Energy, which supplies the Company's LNG plant in California and DGS's plant in Arizona where the Company has a take or pay obligation. During 2010, 2011 and 2012, the Company incurred approximately 17%, 16%, and 16%, respectively, of its natural gas costs related to its CNG operations from the SoCal Gas Company and San Diego Gas and Electric. Any inability to obtain natural gas in the amounts needed on a timely basis or at commercially reasonable prices could result in interruption of gas deliveries or increases in gas costs, which could have a material adverse effect on the Company's business, financial condition, and results of operations until alternative sources could be developed at a reasonable cost.
XML 69 R68.htm IDEA: XBRL DOCUMENT v2.4.0.6
Income Taxes (Details 2) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2012
Federal
  
Income Taxes  
Operating loss carryforwards $ 190,584
State
  
Income Taxes  
Operating loss carryforwards 184,531
Federal and state
  
Income Taxes  
Capital loss carryforwards 14,544
Foreign
  
Income Taxes  
Operating loss carryforwards $ 27,054
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Consolidated Statements of Cash Flows (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Cash flows from operating activities:      
Net loss $ (100,862) $ (47,455) $ (2,773)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:      
Depreciation and amortization 36,261 30,406 22,487
Asset impairments 14,544   2,248
Provision for doubtful accounts and notes 1,358 344 264
Loss on disposal of assets     181
Derivative gain (3,391) (2,655) (10,278)
Stock-based compensation expense 22,087 13,473 11,920
Amortization of debt issuance cost 551 339  
Accretion of notes payable 2,016 2,731 1,118
Gain on contingent consideration for acquisitions (4,112) (2,828) (1,184)
Changes in operating assets and liabilities, net of assets and liabilities acquired:      
Accounts and other receivables 1,832 (137) (32,679)
Inventory (1,879) (14,782) (4,882)
Margin deposits on futures contracts 3,000 2,981 (3,706)
Prepaid expenses and other assets 4,201 (14,709) (851)
Accounts payable (328) 324 (503)
Accrued expenses and other 4,966 4,832 7,935
Net cash used in operating activities (19,756) (27,136) (10,703)
Cash flows from investing activities:      
Purchases of short-term investments (55,062) (33,329)  
Maturities of short-term investments 49,504    
Purchases of property and equipment (192,894) (66,687) (40,828)
Proceeds from sale of property and equipment     282
Loans made to customers (10,521) (5,591) (4,555)
Payments on and proceeds from sales of loans receivable 8,251 2,508 3,934
Acquisitions, net of cash acquired 269 (1,000) (20,473)
Investments in other entities (1,437) (4,712) (427)
Restricted cash 37,943 (57,096)  
Net cash used in investing activities (163,947) (165,907) (62,067)
Cash flows from financing activities:      
Proceeds from minority interest DCE equity contribution   417  
Proceeds from exercise of warrants   150,000 11,537
Proceeds from issuance of common stock     42,562
Proceeds from the exercise of stock options 8,969 1,477 11,049
Proceeds from debt instruments 50,612 244,455 200
Proceeds from revolving line of credit 39,164 53,595 12,665
Repayment of borrowing under revolving line of credit (34,735) (49,589) (14,348)
Repayment of capital lease obligations and debt instruments (10,040) (17,079) (1,050)
Contingent consideration paid relating to business acquisitions (350) (2,394)  
Payment for debt issuance costs   (3,054)  
Net cash provided by financing activities 53,620 377,828 62,615
Effect of exchange rates on cash and cash equivalents 480 (1,854) (1,738)
Net increase (decrease) in cash and cash equivalents (129,603) 182,931 (11,893)
Cash and cash equivalents, beginning of year 238,125 55,194 67,087
Cash and cash equivalents, end of year 108,522 238,125 55,194
Supplemental disclosure of cash flow information:      
Income taxes paid 1,160 783 222
Interest paid, net of $434, $1,352, and $6,304 capitalized, respectively $ 13,994 $ 6,744 $ 2,251
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Consolidated Balance Sheets (Parenthetical) (USD $)
In Thousands, except Share data, unless otherwise specified
Dec. 31, 2012
Dec. 31, 2011
Consolidated Balance Sheets    
Accounts receivable, allowance for doubtful accounts (in dollars) $ 905 $ 712
Preferred stock, par value (in dollars per share) $ 0.0001 $ 0.0001
Preferred stock, Authorized shares 1,000,000 1,000,000
Preferred stock, issued shares 0 0
Preferred stock, outstanding shares 0 0
Common stock, par value (in dollars per share) $ 0.0001 $ 0.0001
Common stock, Authorized shares 149,000,000 149,000,000
Common stock, issued shares 87,634,478 85,433,258
Common stock, outstanding shares 87,634,478 85,433,258
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Long-term Debt
 12 Months Ended
Dec. 31, 2012
Long-term Debt  
Long-term Debt

(9) Long-term Debt

        In conjunction with the Company's acquisition of its 70% interest in Dallas Clean Energy, LLC ("DCE"), on August 15, 2008, the Company entered into a credit agreement ("Credit Agreement") with PlainsCapital Bank ("PCB"). The Company borrowed $18,000 (the "Facility A Loan") to finance the acquisition of its membership interests in DCE. The Company also obtained a $12,000 line of credit from PCB to finance capital improvements of the DCE processing facility and to pay certain costs and expenses related to the acquisition and the PCB loans (the "Facility B Loan").

        On October 7, 2009, the Facility A Loan was repaid in full and converted into a $20,000 line of credit (the "A Line of Credit") pursuant to an amendment to the Credit Agreement. On August 13, 2010, the Credit Agreement was amended to extend the maturity date of the A Line of Credit to August 14, 2011 and add an unused facility fee. The amendment also provided for a 1-year option to extend the maturity date to August 14, 2012, subject to the Company not being in default on the A Line of Credit. The unused facility fees are to be paid quarterly, in an amount equal to one-tenth of one percent (0.10%) of the unused portion. The Company elected not to renew the A Line of Credit on August 14, 2011 and the Line of Credit expired on that date. The principal amount of the Facility B Loan became due and payable in annual payments commencing on August 1, 2009, and continuing each anniversary date thereafter, with each such payment being in an amount equal to the lesser of twenty percent of the aggregate principal amount of the Facility B Loan then outstanding or $2,800. Pursuant to an amendment to the Facility B loan between the Company and PCB dated November 1, 2010, PCB agreed to forgo the scheduled payment due from the Company on August 2010 in the amount of $2,059 until January 31, 2011, which payment was made on such date. On March 31, 2011, the Company paid in full the remaining principal and interest that was due under the Facility B Loan.

        In conjunction with the DCE acquisition mentioned above, the Company also entered into a Loan Agreement with DCE (the "DCE Loan") to provide secured financing of up to $14,000 to DCE for future capital expenditures or other uses as agreed to by the Company, in its sole discretion. On March 31, 2011, the entire amount of unpaid principal and interest due under the DCE Loan was paid to the Company. The interest income related to the DCE Loan has been eliminated in the accompanying consolidated statements of operations.

Revenue Bonds

        On March 25, 2011, the Company's 70% owned subsidiary, Dallas Clean Energy McCommas Bluff, LLC, a Delaware limited liability company ("DCEMB"), arranged for a $40,200 tax-exempt bond issuance (the "Revenue Bonds"). The Revenue Bonds will be repaid from the revenue generated by DCEMB from the sale of RNG. The Revenue Bonds are secured by the revenue and assets of DCEMB and are non-recourse to DCEMB's direct and indirect parent companies, including the Company. The bond repayments are amortized through December 2024 and the average coupon interest rate on the bonds is 6.60%. The bond issuance closed March 31, 2011.

        The bond proceeds will primarily be used to finance further improvements and expansion of the landfill gas processing facility owned by DCEMB at the McCommas Bluff landfill outside of Dallas, Texas. A portion of the proceeds were used to retire the DCE Loan discussed above. The Company, in turn, used the proceeds from the payoff of the DCE Loan to repay approximately $8,000 owed by the Company to PCB under the Facility B Loan on March 31, 2011.

        Pursuant to the Loan Agreement, dated as of January 1, 2011 (the "Loan Agreement"), between DCEMB and the Mission Economic Development Corporation (the "Issuer"), DCEMB has covenanted with the Issuer to make loan repayments equal to the principal and interest coming due on the Revenue Bonds. DCEMB executed a promissory note, dated March 31, 2011 (the "Note"), as evidence of its obligations under the Loan Agreement. Pursuant to the Trust Indenture, dated as of January 1, 2011 (the "Indenture"), the Issuer has pledged and assigned to the Trustee all of the Issuer's right, title and interest in and to the Loan Agreement (with certain specified exceptions) and the Note.

        The obligations of DCEMB under the Loan Agreement are secured by a Leasehold Deed of Trust, Assignment of Rents, Security Agreement and Fixture Filing, dated as of January 1, 2011 (the "Deed of Trust"), executed by DCEMB in favor of the deed of trust trustee named therein for the benefit of the Bank of New York Mellon Trust Company, N.A., as Trustee (the "Trustee"). In addition, DCEMB executed a Security Agreement (the "Security Agreement"), as security for its obligations, pursuant to which DCEMB granted to the Trustee a security interest in all right, title and interest of DCEMB to the Collateral (as defined in the Security Agreement), which includes, but is not limited to, DCEMB's rights, title and interest in any gas sale agreements, including the gas sale agreement with Shell Energy North America (US), L.P. (the "Shell Gas Sale Agreement"), and the funds and accounts held under the Indenture.

        Pursuant to a Consent and Agreement, by and between Shell Energy, The Bank of New York Mellon Trust Company, N.A., as Depository Bank (the "Depository Bank"), DCEMB and the Trustee, dated as of January 1, 2011 (the "Consent Agreement"), Shell Energy agreed to make all payments due to DCEMB under the Shell Gas Sale Agreement to the Depository Bank. In addition, other revenues generated through the sale of gas produced at the facility will be paid directly to the Depository Bank pursuant to a Depository and Control Agreement, dated as of January 1, 2011 (the "Depository Agreement"), among DCEMB, the Trustee and the Depository Bank.

        All payments received by the Depository Bank will be placed into various accounts in accordance with the requirements of the Indenture and the Depository Agreement. The funds in these accounts will be used to service required debt payments, finance further improvements and expansion of the landfill gas processing facility owned by DCEMB, finance the operations and maintenance of DCEMB, finance certain expenses associated with setting up and maintaining the accounts, and other uses as prescribed in the Depository Agreement. The Depository Bank will make payments out of these accounts in accordance with the requirements of the Depository Agreement. At the end of each month after all required account fundings have been fulfilled in accordance with the Depository Agreement, all remaining excess funds will be placed into a Surplus Account. The funds in the Surplus Account will be delivered to DCEMB so long as (i) DCEMB's Debt Service Coverage Ratio (as defined) for the most recent four calendar quarters then ended equals or exceeds 1.25:1, (ii) DCEMB's Debt Service Coverage Ratio (as defined) is reasonably projected to equal or exceed 1.25:1 for the next four calendar quarters, (iii) no events of default have occurred as defined by the Indenture and the Loan Agreement, and (iv) after giving effect to the transfer, DCEMB's Minimum Days Cash on Hand (as defined) shall be, or shall at any time be projected to be, more than the lesser of thirty-five Days Cash on Hand (as defined) or $1,300. Due to these restrictions on this cash, the Company has classified all of this cash as restricted cash on the balance sheet. The Company records the restricted cash that is expected to be received and used within the next 12 months from the Depository Bank for working capital and operating purposes as current in its balance sheet, and presents the remaining balance as non-current in the line item notes receivable and other long term assets. At December 31, 2012, $952 was recorded as long term restricted cash and $7,776 was recorded as short term restricted cash in the accompanying consolidated balance sheet.

        Pursuant to a Collateral Assignment and Consent Agreement with Atmos Pipeline—Texas ("Atmos"), DCEMB has collaterally assigned to the Trustee, subject to certain reserved rights and the consent of Atmos, the transportation agreements of the Company with Atmos.

        The Indenture and the Loan Agreement have certain non-financial debt covenants with which DCEMB must comply. As of December 31, 2012, DCEMB was in compliance with all its debt covenants.

Purchase Notes

        In connection with the closing of the Company's acquisition of IMW, the Company agreed to make future payments consisting of four annual payments in the amount of $12,500 which were subsequently amended to be CAD$5,000 and $7,500. Each payment under the IMW Notes will consist of CAD$5,000 in cash and $7,500 in cash and/or shares of the Company's common stock (the exact combination of cash and/or stock to be determined at the Company's option). In addition, pursuant to a security agreement executed at closing, the IMW Notes are secured by a subordinate security interest in IMW. In January 2011, the Company paid $5,000 in cash and $7,500 in shares of its common stock. The Company paid CAD$5,000 in cash in January 2012 and $3,750 in shares of its common stock in each of August 2012 and October 2012. The Company paid CAD$5,000 in cash and $7,500 in shares of its common stock in February 2013. The IMW Notes that were settled with shares of the Company's common stock are not included in the consolidated statements of cash flows as they are non-cash financing activities.

        In connection with the closing of the Company's acquisition of Northstar, the Company agreed to make future payments consisting of five annual payments in the amount of $700 each with the first payment due December 15, 2011. Each of the first two payments of $700 was paid in December 2011 and 2012, respectively.

        In connection with the closing of the Company's acquisition of the natural gas fuel infrastructure construction business of Weaver Electric, Inc. on October 3, 2011, the Company paid $1,000 in cash and agreed to make four additional annual payments in the amount of $250 each with the first payment due October 3, 2012 (the "Weaver Notes"). In May 2012, the Company prepaid $125 of the October 2012 payment, and the remaining amount of such payment was paid in October 2012.

        In connection with the closing of the Company's acquisition of ServoTech on April 30, 2012, the Company paid $1,400 in cash at closing and paid an additional $1,400 in cash on October 31, 2012.

        The difference between the carrying amount and the face amount of these obligations is being accreted to interest expense over the remaining term of the obligations.

HSBC Lines of Credit

        In connection with the closing of the Company's acquisition of IMW, the Company entered into an Assumption Agreement (the "Assumption Agreement") with HSBC Bank Canada ("HSBC") pursuant to which the Company assumed the obligations and liabilities of IMW under the following arrangements with HSBC (collectively, the "IMW Lines of Credit"):

  • (i)
    An operating line of credit with a limit of $13,000 in Canadian dollars ("CAD") to assist in financing the day-to-day working capital needs of IMW. The interest on amounts outstanding shall be payable at IMW's option at (a) HSBC's Prime Rate plus 1.00% per annum, (b) HSBC's U.S. Base Rate plus 1.00% per annum, or LIBOR plus 2.25% per annum, subject to availability.

    (ii)
    A demand revolving line of credit with a limit of CAD$2,000 bearing interest at the same rate as that of the operating line of credit discussed above, to assist in financing IMW's import requirements.

    (iii)
    A demand revolving bank guarantee and standby letter of credit line with a limit of CAD$1,115.

    (iv)
    A bank guarantee line with a limit of CAD$3,000, which allows IMW to provide guarantees and/or standby letters of credit to overseas suppliers or bid/performance deposits on contracts.

    (v)
    A forward exchange contract line with a limit of CAD$13,750 that allows IMW to enter into foreign exchange forward contracts up to the notional limit of CAD$13,750 (no forward exchange contracts were outstanding at December 31, 2012).

    (vii)
    An operating line of credit with a limit of 5,000 Renminbi ("RMB") (CAD$789) bearing interest at the 6 month People's Bank of China rate plus 2.5% and a sub-limit bank guarantee line of 5,000 RMB. The aggregate of the balances in the lines cannot exceed 5,000 RMB.

    (viii)
    A 16,750 Bengali Taka (CAD$209) operating line of credit bearing interest at 14%.

    (ix)
    A 170,000 Columbian Peso (CAD$95) operating line of credit bearing interest at the Colombia benchmark rate plus 7 to 12%.

        The IMW Lines of Credit are secured by a general security agreement providing a first priority security interest in all present and after acquired personal property of IMW, including specific charges on all serial numbered goods, inventory and other assets and assignment of risk insurance (the "Security"). The IMW Lines of Credit contain no fixed repayment terms or mandatory principal payments and are due on demand. Based on the relevant accounting guidance, the Company has classified this debt pursuant to the credit agreement as short-term given that it is due on demand.

        The Assumption Agreement with HSBC sets forth certain financial covenants with which IMW must comply, including: 1) its ratio of debt to tangible net worth must be no greater than 3.75 to 1.0 from January 1, 2012 through March 31, 2012, and no greater than 3.5 to 1.0 from April 1, 2012 through June 30, 2012, and no greater than 3.0 to 1.0 on or after July 1, 2012, 2) it must maintain a tangible net worth of at least CAD$7,000 and 3) its ratio of current assets to current liabilities may not be less than 1.15 to 1.0 until March 31, 2012 or less than 1.25 to 1.0 on or after April 1, 2012. IMW was in compliance with the financial covenants as of December 31, 2012.

        In addition, the Company and IMW agreed that should the making of any scheduled payment by IMW to the seller of IMW under the IMW Notes result in IMW being in breach of the Assumption Agreement, the IMW Lines of Credit or the Security, the Company shall furnish IMW with the funds needed to remain in compliance with the Assumption Agreement, the IMW Lines of Credit and the Security. Further, the Company and IMW agreed that should IMW make any future earn-out payments to the seller of IMW in connection with the acquisition of IMW, and should the making of such earn-out payments result in IMW being in breach of the Assumption Agreement, the IMW Lines of Credit or the Security, then the Company shall furnish IMW with the funds needed to make such earn-out payments and remain in compliance with the Assumption Agreement, the IMW Lines of Credit and the Security.

Chesapeake 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 for the development, construction and operation of liquefied natural gas stations (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"). Chesapeake Energy Corporation guaranteed Chesapeake's commitment to purchase the CHK Notes under the CHK Agreement.

        The first CHK Note was issued on July 11, 2011, the second CHK Note was issued on July 10, 2012 and the Company expects to issue the third CHK Note on or about June 28, 2013. The CHK Notes bear interest at the rate of 7.5% per annum (payable quarterly, in arrears, on March 31, June 30, September 30 and December 31 of each year) and are convertible at Chesapeake's option into shares of the Company's common stock at a conversion price of $15.80 per share (the "CHK Conversion Price"). Subject to certain restrictions, the Company can force conversion of each CHK Note into shares of the Company's common stock if, following the second anniversary of the issuance of a CHK Note, the Company's shares of common stock trade at a 40% premium to the CHK Conversion Price for at least 20 trading days in any consecutive 30 trading day period. The entire principal balance of each CHK Note is due and payable seven years following its issuance, and the Company may repay each CHK Note in shares of the Company's common stock or cash. The CHK Agreement restricts the use of the CHK Financing proceeds to financing the development, construction and operation of liquefied natural gas stations and payment of certain related expenses. At December 31, 2012, approximately $12,256 of these funds were included in long term restricted cash as the Company anticipates primarily using the funds to build LNG fueling stations. The CHK Agreement also provides for customary events of default which, if any of them occurs, would permit or require the principal of, and accrued interest on, the CHK Notes to become, or to be declared, due and payable.

        In connection with the CHK Financing, the Company also entered into a Registration Rights Agreement, dated July 11, 2011, with Chesapeake (the "CHK Registration Rights Agreement") pursuant to which the Company agreed, subject to the terms and conditions of the CHK Registration Rights Agreement, to (i) file with the Securities and Exchange Commission one or more registration statements relating to the resale of the Company's common stock issuable upon conversion of the CHK Notes, and (ii) at the request of Chesapeake, to participate in one or more underwritten offerings of the Company's common stock issuable upon conversion of the CHK Notes. If the Company does not meet certain of its obligations under the CHK Registration Rights Agreement with respect to the registration of the Company's common stock, it will be required to pay monthly liquidated damages of 0.75% of the principal amount of the CHK Note represented by the Company's common stock included (or to be included, as the case may be) in the applicable registration statement until the related obligation is met. As of December 31, 2012, the Company met its obligations under the CHK Registration Rights Agreement.

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 (payable quarterly, in arrears, on March 31, June 30, September 30 and December 31 of each year) 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"). Subject to certain restrictions, the Company can force conversion of each SLG Note into shares of the Company's common stock if, following the second anniversary of the issuance of the SLG Notes, the Company's shares of common stock 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 the Company's common stock or cash. The SLG 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 SLG Notes to become, or to be declared, due and payable. 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. Such conversion is not included in the consolidated statements of cash flows as it is a non-cash financing activity.

        In connection with the SLG Agreements, the Company also entered into a Registration Rights Agreement, dated August 30, 2011, with each of the Purchasers (the "SLG Registration Rights Agreements") pursuant to which the Company agreed, subject to the terms and conditions of the SLG Registration Rights Agreements, to (i) file with the Securities and Exchange Commission one or more registration statements relating to the resale of the Company's common stock issuable upon conversion of the SLG Notes, and (ii) at the request of the Purchasers, participate in one or more underwritten offerings of the Company's common stock issuable upon conversion of the SLG Notes. If the Company does not meet certain of its obligations under the SLG Registration Rights Agreements with respect to the registration of the Company's common stock, it will be required to pay monthly liquidated damages of 0.75% of the principal amount of the SLG Note represented by the Company's common stock included (or to be included, as the case may be) in the applicable registration statement until the related obligation is met, not to exceed 4% of the aggregate principal amount of the SLG Notes per annum. As of December 31, 2012, the Company met its obligations under the SLG Registration Rights Agreement.

GE Loans

        On November 7, 2012, the Company, through two wholly owned subsidiaries (the "Borrowers"), entered into a financing arrangement with General Electric ("GE Credit Agreement"). Pursuant to the GE Credit Agreement, GE Capital agreed to loan to the Borrowers up to an aggregate of $200,000 to finance the development, construction and operation of two LNG production facilities (individually a "Project" and together the "Projects"), each with an expected production capacity of approximately 250,000 LNG gallons per day. The Company expects to sell the LNG produced by the Projects through America's Natural Gas Highway, a nationwide network of LNG truck fueling stations, which the Company is building along major transportation corridors in the United States.

        The Borrowers' ability to obtain loans under the GE Credit Agreement (collectively, "Loans" and, with respect to each Project "Tranche A Loans" and "Tranche B Loans") for the Projects 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, (iii) commitment of all utility services necessary for the construction and operation of the Projects, and (iv) execution of an engineering, procurement and construction contract for each Project by the Company and GE Oil & Gas, Inc.

        The GE Credit Agreement further provides that (i) if initial Loans are not made prior to December 31, 2014, the GE Credit Agreement will automatically terminate, (ii) each Project must be completed by the earlier of (a) the date thirty months after the funding of the initial Loans with respect to such Project and (b) December 31, 2016 (with respect to each Project, the "Date Certain"), (iii) 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, (iv) each Term Loan will be due and payable on the eighth anniversary of the Conversion Date with respect to such Term Loan, and (v) 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 GE Credit Agreement the then-current LIBOR rate will always be at least 1.00%. The GE Credit Agreement includes various customary covenants, including debt service coverage ratios, 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 December 31, 2012, the Company has not drawn any money under the GE Credit Agreement and was in compliance with the financial covenants.

        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 GE 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 Clean Energy to provide, concurrent with GE's extension of the initial Loans under the GE 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 GE Credit Agreement, the Company issued to GE a warrant to purchase up to 5,000,000 shares of the Company's common stock (see note 11).

        Long-term debt at December 31, 2011 and 2012 consisted of the following:

 
   December 31,
2011		   December 31,
2012		  

IMW Notes

   $ 34,400   $ 23,983  

Northstar future payments

     2,388     1,848  

DCEMB notes

     585     585  

DCEMB Revenue Bonds (non recourse to the Company)

     39,400     38,700  

CHK Notes

     50,000     100,000  

SLG Notes

     150,000     149,000  

Weaver Notes

     872     680  

IMW assumed debt

     6,657     12,661  

Capital lease obligations

     5,120     3,568  
           

Total debt and capital lease obligations

     289,422     331,025  

Less amounts due within one year and short-term borrowings

     (22,925 )   (30,389 )
           

Total long-term debt and capital lease obligations

   $ 266,497   $ 300,636  
           

        The following is a summary of aggregate maturities of long-term debt for each of the years ending December 31:

 
   2013   2014   2015   2016   2017   Thereafter  

IMW Notes

   $ 12,448   $ 11,535   $ —   $ —   $ —   $ —  

Northstar future payments

     662     617     569     —     —     —  

DCEMB notes

     585     —     —     —     —     —  

DCEMB Revenue Bonds

     2,200     2,415     2,540     2,675     2,830     26,040  

CHK Notes

     —     —     —     —     —     100,000  

SLG Notes

     —     —     —     149,000     —     —  

Weaver Notes

     241     227     212     —     —     —  

IMW assumed debt

     12,361     300     —     —     —     —  

Capital lease obligations

     1,892     1,157     395     34     35     55  
                           

Total

   $ 30,389   $ 16,251   $ 3,716   $ 151,709   $ 2,865   $ 126,095  
                           
XML 74 R1.htm IDEA: XBRL DOCUMENT v2.4.0.6
Document and Entity Information (USD $)
 12 Months Ended
Dec. 31, 2012
Feb. 22, 2013
Jun. 30, 2012
Document and Entity Information      
Entity Registrant Name Clean Energy Fuels Corp.    
Entity Central Index Key 0001368265    
Document Type 10-K    
Document Period End Date Dec. 31, 2012    
Amendment Flag false    
Current Fiscal Year End Date --12-31    
Entity Well-known Seasoned Issuer Yes    
Entity Voluntary Filers No    
Entity Current Reporting Status Yes    
Entity Filer Category Large Accelerated Filer    
Entity Public Float     $ 1,048,772,532
Entity Common Stock, Shares Outstanding   88,355,226  
Document Fiscal Year Focus 2012    
Document Fiscal Period Focus FY    
XML 75 R18.htm IDEA: XBRL DOCUMENT v2.4.0.6
Derivative Transactions
 12 Months Ended
Dec. 31, 2012
Derivative Transactions  
Derivative Transactions

(10) Derivative Transactions

        The Company marks to market its open futures positions at the end of each period and records the net unrealized gain or loss during the period in derivative (gains) losses in the consolidated statements of operations or in accumulated other comprehensive income in the consolidated balance sheets in accordance with the applicable accounting guidance. In the years ended December 31, 2010, 2011, and 2012, the Company recorded unrealized (gains) losses of 4,231, ($2,091), and $(2,151) in other comprehensive income (loss) related to its futures contracts. Of the Company's net futures contracts liability of $107 at December 31, 2012, $5 was recorded as an asset in prepaid expenses and other current assets and a liability of $112 was recorded in accrued liabilities in the Company's consolidated balance sheet as of December 31, 2012. Of the $2,355 liability for the Company's futures contracts at December 31, 2011, $2,259 is included in accrued liabilities for the short-term amount, and $96 is included in other long-term liabilities for the long-term amount in the Company's consolidated balance sheet as of December 31, 2011. The Company's ineffectiveness related to its futures contracts in the years ended December 31, 2011 and 2012 was insignificant. During the years ended December 31, 2010, 2011 and 2012, the Company recognized a loss of $1,781, $3,332 and $2,370, respectively, in cost of sales in the accompanying consolidated statement of operations related to its futures contracts that were settled during the respective years. These amounts were reclassified from accumulated other comprehensive income (loss). As of December 31, 2012, the remaining unrecognized loss of $107 is recorded as a component of accumulated other comprehensive income (loss). The Company expects to reclassify such unrecognized loss from accumulated other comprehensive income (loss) as cost of sales through June 30, 2013.

        The following table presents the notional amounts and weighted average fixed prices per gasoline gallon equivalent of the Company's natural gas futures contracts as of December 31, 2012:

 
   Gallons   Weighted
Average Price
Per Gasoline
Gallon
Equivalent		  

2013

     1,140,000   $ 0.53  
XML 76 R80.htm IDEA: XBRL DOCUMENT v2.4.0.6
Subsequent Events (Details) (USD $)
In Thousands, except Share data, unless otherwise specified
 12 Months Ended 2 Months Ended 12 Months Ended 0 Months Ended
Dec. 31, 2011
Dec. 31, 2010
Feb. 28, 2013
Subsequent event
SLG Notes
Dec. 31, 2012
Subsequent event
Peru JV
Jan. 02, 2013
Subsequent event
Estimated amount to be recognized in first quarter of 2013
Subsequent Events          
Extension of VETC, 2012 credits to be recognized in 2013 $ 17,889 $ 16,042     $ 20,800
Ownership interest sold       6,100  
Dividend distribution       1,027  
Amount of principal converted into stock     $ 4,030    
Common stock issued upon conversion of debt (in shares)     268,664    
XML 77 R4.htm IDEA: XBRL DOCUMENT v2.4.0.6
Consolidated Statements of Operations (USD $)
In Thousands, except Share data, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Revenue:      
Product revenues $ 293,777 $ 260,283 $ 189,836
Service revenues 40,231 32,434 21,998
Total revenue 334,008 292,717 211,834
Cost of sales:      
Product cost of sales 236,471 200,908 132,911
Service cost of sales 17,213 15,776 8,978
Derivative gains:      
Series I warrant valuation (3,391) (2,655) (10,278)
Selling, general and administrative 117,976 86,850 63,258
Depreciation and amortization 36,261 30,406 22,487
Total operating expenses 404,530 331,285 217,356
Operating loss (70,522) (38,568) (5,522)
Interest expense, net (16,069) (9,616) (1,194)
Other income (expense), net 1,236 (611) 2,080
Impairment of cost method investment (14,544)    
Income from equity method investments 331 637 427
Loss before income taxes (99,568) (48,158) (4,209)
Income tax (expense) benefit (1,294) 703 1,436
Net loss (100,862) (47,455) (2,773)
Loss (income) of noncontrolling interest (393) (178) 257
Net loss attributable to Clean Energy Fuels Corp. $ (101,255) $ (47,633) $ (2,516)
Loss per share:      
Basic (in dollars per share) $ (1.16) $ (0.68) $ (0.04)
Diluted (in dollars per share) $ (1.16) $ (0.68) $ (0.04)
Weighted average common shares outstanding:      
Basic (in shares) 87,455,073 70,415,431 62,549,311
Diluted (in shares) 87,455,073 70,415,431 62,549,311
XML 78 R12.htm IDEA: XBRL DOCUMENT v2.4.0.6
Investments
 12 Months Ended
Dec. 31, 2012
Investments  
Investments

(4) 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.

        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 December 31, 2012 the Company believes its cost bases for its available-for-sale investments are properly recorded.

        Short-term investments as of December 31, 2011 are summarized as follows:

 
   Amortized Cost   Gross Unrealized Losses   Estimated Fair Value  

Municipal bonds & notes

   $ 19,703   $ (114 ) $ 19,589  

Zero coupon bonds

     712     —     712  

Corporate bonds

     3,040     (12 )   3,028  
               

Total available-for-sale securities

     23,455     (126 )   23,329  

Certificate of deposits

     10,000     —     10,000  
               

Total short-term investments

   $ 33,455   $ (126 ) $ 33,329  
               

        Short-term investments as of December 31, 2012 are summarized as follows:

 
   Amortized Cost   Gross Unrealized Losses   Estimated Fair Value  

Municipal bonds & notes

   $ 23,755   $ (105 ) $ 23,650  

Corporate bonds

     4,557     (53 )   4,504  
               

Total available-for-sale securities

     28,312     (158 )   28,154  

Certificate of deposits

     10,021     —     10,021  
               

Total short-term investments

   $ 38,333   $ (158 ) $ 38,175  
               
XML 79 R11.htm IDEA: XBRL DOCUMENT v2.4.0.6
Restricted Cash
 12 Months Ended
Dec. 31, 2012
Restricted Cash  
Restricted Cash

(3) Restricted Cash

        The Company classifies restricted cash as 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, 2011 and 2012:

 
   December 31, 2011   December 31, 2012  

Short-term restricted cash

              

Standby letters of credit

   $ 1,237   $ 669  

DCEMB bonds—current operating costs

     3,555     7,776  
           

Total short-term restricted cash

     4,792     8,445  

Chesapeake loan

     40,322     12,256  

DCEMB bonds—long-term plant expansion

     14,482     952  
           

Total restricted cash

   $ 59,596   $ 21,653  
           
XML 80 R23.htm IDEA: XBRL DOCUMENT v2.4.0.6
401(k) Plan
 12 Months Ended
Dec. 31, 2012
401(k) Plan  
401(k) Plan

(15) 401(k) Plan

        The Company has established a savings plan ("Savings Plan") which is qualified under Section 401(k) of the Internal Revenue Code. Eligible employees may elect to make contributions to the Savings Plan through salary deferrals of up to 90% of their base pay, subject to Internal Revenue Code limitations. The Company may make discretionary contributions to the Savings Plan that are subject to limitations. For the years ended December 31, 2010, 2011 and 2012, the Company contributed approximately $551, $798, and $1,289 of matching contributions to the Savings Plan, respectively.
XML 81 R19.htm IDEA: XBRL DOCUMENT v2.4.0.6
Stockholders' Equity
 12 Months Ended
Dec. 31, 2012
Stockholders' Equity  
Stockholders' Equity

(11) Stockholders' Equity

Authorized Shares

        The Company's certificate of incorporation authorizes the issuance of two classes of capital stock designated as common stock and preferred stock, each having $0.0001 par value per share. As of December 31, 2012, the Company was authorized to issue 150,000,000 shares, of which 149,000,000 shares are designated common stock and 1,000,000 shares are designated preferred stock.

Dividend Provisions

        The Company did not declare nor pay any dividends during the years ended December 31, 2010, 2011 or 2012.

Voting Rights

        Each holder of common stock has the right to one vote per share owned on matters presented for stockholder action.

Issuance of Common Stock

        On November 11, 2010, the Company issued 3,450,000 shares of common stock at a price of $13.25 per share, including 50,068 shares purchased by key executives of the Company, and the exercise in full by the underwriters of their option to purchase 450,000 additional shares of the Company's common stock. The purchase price paid by the key executives of the Company was $14.48 per share, which was the consolidated closing bid price of the Company's common stock on the NASDAQ Global Market on November 10, 2010. The Company received aggregate net proceeds of $42,562 after deducting underwriting discounts and commissions and offering expenses payable by the Company.

Issuance of Common Stock and Warrants

        On October 28, 2008, the Company entered into a Placement Agent Agreement (the "Placement Agent Agreement") relating to the sale and issuance by the Company to select investors of 4,419,192 units (the "Units"), with each Unit consisting of (i) one share of the Company's common stock, par value $0.0001 per share, (ii) a warrant to purchase 0.75 shares of Common Stock (the "Series I Warrant"), and (iii) one warrant to purchase up to 0.2571 shares of Common Stock (the "Series II Warrant"). The price of each Unit was $7.92 per Unit. The transaction closed on November 3, 2008, and the Company issued 4,419,192 shares of common stock, Series I Warrants to purchase up to 3,314,394 shares of Common Stock, and Series II Warrants to purchase up to 1,136,364 shares of Common Stock. The Company received approximately $32,484 after deducting the placement agent's fees and other offering expenses related to the Unit sale. The proceeds of $32,484 were allocated between the common stock, the Series I Warrants and the Series II Warrants. The Company allocated $19,166, $9,745 and $3,573 to the common stock, the Series I Warrants and the Series II Warrants, respectively.

        The Series I Warrants became exercisable beginning six months from the date of issuance for a period of seven years from the date they become exercisable, and carry an exercise price of $12.68 per share. On November 10, 2010, the Company entered into an amendment with one of the holders of the Series I warrants pursuant to which the expiration date of such warrant for the purchase of 1,183,712 shares of common stock was changed to November 10, 2010. In consideration of the modification to the expiration date, the Company agreed to pay the holder of such warrant approximately $3,172. The Company received notice on November 10, 2010 that such warrant was being exercised in full, and issued 1,183,712 shares of its common stock for an aggregate exercise price of approximately $15,009. Upon exercise, the Company recognized a gain of approximately $3,208 related to the transaction. For additional information on the Series I Warrants see note 18.

        The Series II Warrants became exercisable on November 5, 2008 upon the failure of the California Alternative Fuel Vehicles and Renewable Energy Act, or Proposition 10, in the California statewide election. The Series II Warrants were all exercised on a cashless basis at the exercise price of $0.01 per share, which resulted in the issuance of 1,134,759 shares of common stock to the Series II Warrant holders on November 12, 2008.

        Concurrently with the execution of the GE Credit Agreement on November 7, 2012, the Company issued to GE a warrant (the "GE Warrant") to purchase up to an aggregate of five million shares of the Company's common stock, par value $0.0001 per share ("Shares"), at a price per share of $0.01. The Shares subject to the GE Warrant are exercisable pursuant to the following schedule: (i) 500,000 Shares are immediately exercisable, (ii) an additional 1,250,000 shares will become exercisable at the time that the first Tranche A Loan is made under the GE Credit Agreement, (iii) an additional 1,250,000 shares will become exercisable at the time that the first Tranche B Loan is made under the GE Credit Agreement, (iv) an additional 1,000,000 shares will become exercisable at the time that Tranche A Loans in aggregate principal amount of at least $15,000 have been made under the GE Credit Agreement, and (v) the remaining 1,000,000 Shares will become exercisable at the time that Tranche B Loans in aggregate principal amount of at least $15,000 have been made under the GE Credit Agreement; provided, however, that if no Loans are made as contemplated by (ii) through (v) above pursuant to the GE Credit Agreement, an additional 500,000 Shares will be exercisable. The GE Warrant terminates on November 7, 2022. During the exercise period, if the Company issues or sells any shares other than exempted securities (as defined in the GE Warrant) for a price per share less than a price equal to 80% of the market price on the day of such issue or sale (the foregoing a "Dilutive Issuance"), then immediately after such Dilutive Issuance the number of shares then purchasable shall be increased on a proportionate basis by a formula set forth in the GE Warrant.

        In connection with the GE Warrant, on November 7, 2012, the Company and GE entered into a warrant agreement (the "GE Warrant Agreement") and a registration rights agreement (the "GE Registration Rights Agreement"). Pursuant to the GE Registration Rights Agreement, the Company agreed, subject to the terms and conditions of that agreement, to (i) file with the Securities and Exchange Commission one or more registration statements relating to the resale of Shares issuable upon exercise of the GE Warrant, and (ii) at the request of the GE Warrant holder, if a registration statement with respect to the Shares is not then effective, participate in one or more underwritten offerings of Shares issuable upon exercise of the Warrant. If the Company does not meet certain of its obligations under the GE Registration Rights Agreement with respect to the registration of Shares, it will be required to pay certain liquidated damages. As of December 31, 2012, the Company met its obligations under the GE Registration Rights Agreement.

        The Company measured the fair value of the 5,000,000 shares of the GE Warrant at $56,158 and recorded the amount in additional paid-in-capital and other long-term assets as a deferred financing cost. The fair value of the 500,000 shares that are immediately exercisable is being amortized over the estimated term of the GE Credit Agreement on the straight-line basis. The fair value of the remaining 4,500,000 shares will be allocated proportionately to the draws of the related loans as they become exercisable and amortized over the estimated term of the draws using the effective interest method. The issuance of these warrants is not included in the consolidated statements of cash flows as it is a non-cash financing activity.

Conversion of Convertible Debts into Common Stock

        In April 2012, $1,003 of principal and accrued interest under a SLG Note was converted by the holder thereof into 66,888 shares of the Company's common stock.

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 years ended December 31, 2010, 2011 and 2012:

 
   Years Ended December 31,  
 
   2010   2011   2012  

Stock-based compensation expense

   $ 11,920   $ 13,473   $ 22,087  
               

Stock-based compensation expense, net of tax

   $ 11,920   $ 13,473   $ 22,087  
               

  • Stock Option Plans

        In December 2002, the Company adopted its 2002 Stock Option Plan ("2002 Plan"). The board of directors determines eligibility, vesting schedules, and exercise prices for options granted under the 2002 Plan. Options generally have a term of ten years.

        Under the 2002 Plan, eligible persons may be issued options for services rendered to the Company. Under the 2002 Plan, the purchase price per share for each option granted shall not be less than 100% of the fair market value of the Company's common stock on the date of such option grant; provided, however, that the purchase price per share of common stock issued to a 10% stockholder shall not be less than 110% of such fair market value on the date of such option grant. Options generally vest over a three-year period.

        In December 2006, the Company adopted its 2006 Equity Incentive Plan ("2006 Plan"). The 2006 Plan was effective on May 24, 2007, the date the Company completed its initial public offering of common stock. The 2002 Plan became unavailable for new awards upon the effectiveness of the 2006 Plan. If any outstanding option under the 2002 Plan expires or is cancelled, the shares allocable to the unexercised portion of that option will be added to the share reserve under the 2006 Plan and will be available for grant under the 2006 Plan. As of December 31, 2012, the Company had 16,890,500 shares reserved for issuance under its option plans. At December 31, 2012, the Company had 38,715 shares available for grant under the 2006 Plan.

        Option activity for the year ended December 31, 2012 is as follows:

 
   Number of
Shares		   Weighted
Average
Exercise
Price		   Weighted
Average
Remaining
Contractual
Term
(in years)		   Aggregate
Intrinsic
Value		  

Outstanding, December 31, 2011

     10,683,303   $ 10.29              

Options granted

     3,194,000     13.88              

Options exercised

     (1,568,480 )   5.72              

Options forfeited

     (225,146 )   14.18              
                         

Outstanding, December 31, 2012

     12,083,677     11.75     6.54   $ 8,459  
                         

Exercisable, December 31, 2012

     7,981,345     10.65     5.31   $ 14,366  
                         

        As of December 31, 2012, there was $25,547 of total unrecognized compensation cost related to non-vested shares. 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 year ended December 31, 2012 was $11,831.

        The Company plans to issue new shares to its employees upon the employee's exercise of their options. The intrinsic value of all options exercised during 2010, 2011 and 2012 was $4,435, $1,626, and $18,822, respectively.

        The fair value of each option grant is estimated on the date of grant using the Black-Scholes option pricing model with the following assumptions used for grants during the year ended December 31, 2012:

Dividend yield

   0.00%

Expected volatility

   57.6% to 72.8%

Risk-free interest rate

   0.9% to 1.2%

Expected life in years

   6.0

        The weighted-average grant date fair value of options granted during the years ended December 31, 2010, 2011, and 2012, were $10.17, $8.98, and $7.95, respectively. The volatility amounts used during the period were estimated based on a certain peer group of the Company's historical volatility for a period commensurate with the expected life of the options granted, the Company's historical volatility, and the Company's implied volatility of its traded options. The expected lives used during the year were based on historical exercise periods and the Company's anticipated exercise periods for its outstanding options. The risk free rates used during the year were based on the U.S. Treasury yield curve for the expected life of the options at the time of grant. The Company recorded $11,920, $13,473, $14,199 of stock option expense during the years ended December 31, 2010, 2011 and 2012, respectively. The Company has not recorded any tax benefit related to its stock option expense.

  • Restricted Stock Units

        The Company issued restricted stock units ("RSUs") to certain key employees during 2012. A holder of RSUs will receive one share of the Company's common stock for each RSU he holds if (x) between two years and four years from the date of grant 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 RSU grant date (the "Stock Price Condition") and (y) 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 RSUs will be automatically forfeited. The RSUs are subject to the terms and conditions of the Company's Amended and Restated 2006 Equity Incentive Plan and a Notice of Grant of Restricted Stock Unit and Restricted Stock Unit Agreement.

        The fair value of the RSUs was estimated using a binomial lattice model that incorporates a Monte Carlo Simulation (the "Monte Carlo Method").

        The following table summarizes the Company's RSU activity during the year ended December 31, 2012:

 
   Number of
Shares		   Weighted Average
Fair Value at
Grant Date		   Weighted
Average
Remaining
Contractual
Term (in years)		  

Outstanding, December 31, 2011

     —     —        

Granted

     1,545,000   $ 11.42        
                   

Outstanding and non-vested, December 31, 2012

     1,545,000   $ 11.42     3.2  
                   

        As of December 31, 2012, there was $9,753 of total unrecognized compensation cost related to non-vested units. That cost is expected to be recognized over a weighted average period of 1.1 years.

        The fair value of each RSU was estimated on the date of grant using the Monte Carlo Method with the following assumptions:

 
   January 25,
2012		   May 8,
2012		  

Stock price on date of grant

   $ 15.11   $ 16.71  

Dividend yield

     0.00 %   0.00 %

Expected volatility

     56.51 %   58.49 %

Risk-free interest rate

     0.57 %   0.56 %

Expected life in years

     2.1     2.0  

        The volatility amounts used during the period were estimated based on the Company's historical volatility for a period commensurate with the term of the RSUs granted and the Company's implied volatility of its traded options. The expected life of the RSUs was derived using the Monte Carlo Method. The risk free rates used during the year were based on the U.S. Treasury yield curve for the expected term of the RSUs at the date of grant. The Company recorded $7,888 of expense and has not recorded any tax benefit related to the expense of the RSUs during 2012.

Boone Pickens Warrant Agreement

        On December 28, 2006, the Company issued to Boone Pickens a five-year warrant to purchase 15,000,000 shares of the Company's common stock at an exercise price of $10.00 per share. These warrants were exercised in full in December 2011.
XML 82 R15.htm IDEA: XBRL DOCUMENT v2.4.0.6
Investment in Other Entities
 12 Months Ended
Dec. 31, 2012
Investment in Other Entities  
Investment in Other Entities

(7) Investment in Other Entities

        The Company invested in The Vehicle Production Group LLC ("VPG"), a company that developed a natural gas vehicle made in the United States for taxi and paratransit use. The Company has accounted for its investment in VPG under the cost method of accounting as the Company has not had the ability to exercise significant influence over VPG's operations. Through June 2012, the Company invested an additional $1,437 in VPG. In the fourth quarter of 2012, the Company determined there was a decrease in value of its cost method investment in VPG that was other than temporary and accordingly recognized an impairment charge for the full value of its investment of $14,544.

        The Company has invested in Clean Energy del Peru ("Peru JV"), a joint venture in Lima, Peru that operates CNG stations. The Company accounts for its investment in Peru JV under the equity method of accounting as the Company has the ability to exercise significant influence over Peru JV's operations. At December 31, 2012, this investment had a balance of $2,581. The Company has agreed to sell its investment in Peru JV to its joint venture partner (see note 19).
XML 83 R60.htm IDEA: XBRL DOCUMENT v2.4.0.6
Accrued Liabilities (Details) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Accrued Liabilities      
Salaries and wages $ 4,558 $ 5,088  
Accrued gas and equipment purchases 10,091 4,773  
Derivative liability 112 2,259  
Contingent consideration obligations 70 378  
Accrued property and other taxes 4,483 3,043  
Accrued professional fees 1,310 875  
Accrued employee benefits 2,607 1,431  
Accrued warranty liability 2,665 3,130 2,338
Other 4,898 7,278  
Total $ 30,794 $ 28,255  
XML 84 R13.htm IDEA: XBRL DOCUMENT v2.4.0.6
Other Receivables
 12 Months Ended
Dec. 31, 2012
Other Receivables  
Other Receivables

(5) Other Receivables

        Other receivables at December 31, 2011 and 2012 consisted of the following:

 
   2011   2012  

Loans to customers to finance vehicle purchases

   $ 1,789   $ 4,151  

Capital lease receivables

     310     308  

Accrued customer billings

     5,860     6,934  

Fuel tax credits

     5,912     2,780  

Other

     5,730     3,635  
           

 

   $ 19,601   $ 17,808  
           
XML 85 R14.htm IDEA: XBRL DOCUMENT v2.4.0.6
Land, Property and Equipment
 12 Months Ended
Dec. 31, 2012
Land, Property and Equipment  
Land, Property and Equipment

(6) Land, Property and Equipment

        Land, property and equipment at December 31, 2011 and 2012 are summarized as follows:

 
   2011   2012  

Land

   $ 1,198   $ 1,476  

LNG liquefaction plants

     93,109     93,384  

RNG plants

     21,005     23,582  

Station equipment

     118,613     158,447  

LNG trailers

     13,532     13,566  

Other equipment

     26,508     47,143  

Construction in progress

     66,256     198,916  
           

 

     340,221     536,514  

Less accumulated depreciation

     (82,758 )   (108,337 )
           

 

   $ 257,463   $ 428,177  
           

        Included in the land, property and equipment are capitalized software costs of $5,539 and $17,611 as of December 31, 2011 and December 31, 2012, respectively. The accumulated amortization on the capitalized software costs is $3,568 and $5,380 as of December 31, 2011 and December 31, 2012, respectively. The Company recorded $498, $1,635, and $1,812 of amortization expense related to the capitalized software costs in 2010, 2011 and 2012, respectively.

        As of December 31, 2011 and 2012, $9,211 and $12,087 are included in accounts payable balances, respectively, which are related to purchases of property and equipment. These amounts are excluded from the consolidated statements of cash flows as they are non-cash investing activities.
XML 86 R16.htm IDEA: XBRL DOCUMENT v2.4.0.6
Accrued Liabilities
 12 Months Ended
Dec. 31, 2012
Accrued Liabilities  
Accrued Liabilities

(8) Accrued Liabilities

        Accrued liabilities at December 31, 2011 and 2012 consisted of the following:

 
   2011   2012  

Salaries and wages

   $ 5,088   $ 4,558  

Accrued gas and equipment purchases

     4,773     10,091  

Derivative liability

     2,259     112  

Contingent consideration obligations

     378     70  

Accrued property and other taxes

     3,043     4,483  

Accrued professional fees

     875     1,310  

Accrued employee benefits

     1,431     2,607  

Accrued warranty liability

     3,130     2,665  

Other

     7,278     4,898  
           

 

   $ 28,255   $ 30,794  
           
XML 87 R64.htm IDEA: XBRL DOCUMENT v2.4.0.6
Derivative Transactions (Details) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Derivative Transactions      
Unrealized (gains) losses on derivative instruments recognized in other comprehensive income (loss) $ (2,151) $ (2,091) $ 4,231
Short-term liability related to derivative instruments included in accrued liabilities 112 2,259  
Natural gas futures contracts
      
Derivative Transactions      
Unrealized (gains) losses on derivative instruments recognized in other comprehensive income (loss) (2,151) (2,091) 4,231
Derivative liability 107 2,355  
Derivative asset recorded in prepaid expenses and other current assets 5    
Derivative liability recorded in accrued liabilities 112    
Short-term liability related to derivative instruments included in accrued liabilities   2,259  
Long-term liability related to derivative instruments included in other long-term liabilities   96  
Loss on derivative instrument recognized in cost of sales 2,370 3,332 1,781
Remaining unrecognized loss recorded as a component of accumulated other comprehensive income (loss) $ 107    
Natural gas futures contracts | 2013
      
Notional amounts and weighted-average fixed prices per gasoline gallon equivalent of derivative instruments      
Gallons 1,140,000    
Natural gas futures contracts | 2013 | Weighted Average
      
Notional amounts and weighted-average fixed prices per gasoline gallon equivalent of derivative instruments      
Price Per Gasoline Gallon Equivalent 0.53    
XML 88 R66.htm IDEA: XBRL DOCUMENT v2.4.0.6
Stockholders' Equity (Details 2) (USD $)
In Thousands, except Share data, unless otherwise specified
 12 Months Ended 1 Months Ended 12 Months Ended 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2012
Stock options
Dec. 31, 2011
Stock options
Dec. 31, 2010
Stock options
May 31, 2012
Restricted Stock Units
Jan. 31, 2012
Restricted Stock Units
Dec. 31, 2012
Restricted Stock Units
May 08, 2012
Restricted Stock Units
Jan. 25, 2012
Restricted Stock Units
Dec. 31, 2012
Restricted Stock Units
Minimum
Dec. 31, 2012
Restricted Stock Units
Maximum
Dec. 31, 2012
2002 Plan
Stock options
Dec. 31, 2012
2002 Plan
Stock options
Minimum
Dec. 31, 2012
2006 Plan
Stock options
Summary of stock-based compensation expense                                
Stock-based compensation expense $ 22,087 $ 13,473 $ 11,920 $ 14,199 $ 13,473 $ 11,920     $ 7,888              
Stock-based compensation expense, net of tax 22,087 13,473 11,920                          
Expiration term                           10 years    
Purchase price of options expressed as percentage of fair market value of common stock                             100.00%  
Purchase price of options granted to 10% stockholders expressed as percentage of fair market value of common stock                             110.00%  
Percentage ownership of stock for which the option purchase price will be 110% of fair market                           10.00%    
Vesting period                           3 years    
Authorized shares                               16,890,500
Number of shares available for grant                               38,715
Number of Shares                                
Outstanding at the beginning of the period (in shares)       10,683,303                        
Options granted (in shares)       3,194,000                        
Options exercised (in shares)       (1,568,480)                        
Options forfeited (in shares)       (225,146)                        
Outstanding at the end of the period (in shares)       12,083,677 10,683,303                      
Exercisable at the end of the period (in shares)       7,981,345                        
Weighted Average Exercise Price                                
Outstanding at the beginning of the period (in dollars per share)       $ 10.29                        
Options granted (in dollars per share)       $ 13.88                        
Options exercised (in dollars per share)       $ 5.72                        
Options forfeited (in dollars per share)       $ 14.18                        
Outstanding at the end of the period (in dollars per share)       $ 11.75 $ 10.29                      
Exercisable at the end of the period (in dollars per share)       $ 10.65                        
Weighted Average Remaining Contractual Term                                
Outstanding at the end of period       6 years 6 months 14 days                        
Exercisable at the end of period       5 years 3 months 22 days                        
Aggregate Intrinsic Value                                
Outstanding at the end of period       8,459                        
Exercisable at the end of period       14,366                        
Number of Shares                                
Granted                 1,545,000              
Outstanding at the end of the period                 1,545,000              
Weighted Average Fair Value at Grant Date (in dollars per share)                                
Granted                 $ 11.42              
Outstanding at the end of the period                 $ 11.42              
Weighted Average Remaining Contractual Term                                
Weighted Average Remaining Contractual Term                 3 years 2 months 12 days              
Weighted average assumption used for grants in 2012                                
Stock price on date of grant                   $ 16.71 $ 15.11          
Dividend yield (as a percent)       0.00%                        
Expected volatility, minimum (as a percent)       57.60%                        
Expected volatility, maximum (as a percent)       72.80%                        
Expected volatility (as a percent)             58.49% 56.51%                
Risk-free interest rate, minimum (as a percent)       0.90%                        
Risk-free interest rate, maximum (as a percent)       1.20%                        
Risk-free interest rate (as a percent)             0.56% 0.57%                
Expected life       6 years     2 years 2 years 1 month 6 days                
Other disclosures                                
Total unrecognized compensation cost related to non-vested shares       25,547                        
Weighted average period over which the total unrecognized compensation cost related to non-vested units is expected to be recognized       1 year 7 months 6 days         1 year 1 month 6 days              
Total fair value of shares vested       11,831                        
Intrinsic value of all options exercised       18,822 1,626 4,435                    
Number of shares of common stock to be received for each performance unit                 1              
Period from the date of grant in which the closing price of the entity's common stock must exceed the closing price in order for a holder to receive one share of common stock for each award                       2 years 4 years      
Number of consecutive trading days during which the closing price of the entity's common stock must exceed the closing price on the grant date in order for a holder to receive one share of common stock for each award                 20 days              
Period from the date of grant after which awards will be automatically forfeited if the Stock Price Condition is not satisfied                 4 years              
Percentage of the closing price of the entity's common stock that the closing price must equal or exceed in order for an award holder to receive one share of common stock for each award                 135.00%              
Total unrecognized compensation cost related to non-vested units                 $ 9,753              
Weighted-average grant date fair values of options granted       $ 7.95 $ 8.98 $ 10.17                    
XML 89 R63.htm IDEA: XBRL DOCUMENT v2.4.0.6
Long-term Debt (Details 3) (USD $)
In Thousands, unless otherwise specified
Dec. 31, 2012
Dec. 31, 2011
Long-term Debt    
Total debt and capital lease obligations $ 331,025 $ 289,422
Less amounts due within one year and short-term borrowings (30,389) (22,925)
Total long-term debt and capital lease obligations 300,636 266,497
Summary of aggregate maturities of long-term debt    
2013 30,389  
2014 16,251  
2015 3,716  
2016 151,709  
2017 2,865  
Thereafter 126,095  
IMW Notes
    
Long-term Debt    
Total debt and capital lease obligations 23,983 34,400
Summary of aggregate maturities of long-term debt    
2013 12,448  
2014 11,535  
Northstar future payments
    
Long-term Debt    
Total debt and capital lease obligations 1,848 2,388
Summary of aggregate maturities of long-term debt    
2013 662  
2014 617  
2015 569  
DCEMB notes
    
Long-term Debt    
Total debt and capital lease obligations 585 585
Summary of aggregate maturities of long-term debt    
2013 585  
DCEMB Revenue Bonds (non recourse to the Company)
    
Long-term Debt    
Total debt and capital lease obligations 38,700 39,400
Summary of aggregate maturities of long-term debt    
2013 2,200  
2014 2,415  
2015 2,540  
2016 2,675  
2017 2,830  
Thereafter 26,040  
CHK Notes
    
Long-term Debt    
Total debt and capital lease obligations 100,000 50,000
Summary of aggregate maturities of long-term debt    
Thereafter 100,000  
SLG Notes
    
Long-term Debt    
Total debt and capital lease obligations 149,000 150,000
Summary of aggregate maturities of long-term debt    
2016 149,000  
Weaver Notes
    
Long-term Debt    
Total debt and capital lease obligations 680 872
Summary of aggregate maturities of long-term debt    
2013 241  
2014 227  
2015 212  
IMW assumed debt
    
Long-term Debt    
Total debt and capital lease obligations 12,661 6,657
Summary of aggregate maturities of long-term debt    
2013 12,361  
2014 300  
Capital lease obligations
    
Long-term Debt    
Total debt and capital lease obligations 3,568 5,120
Summary of aggregate maturities of long-term debt    
2013 1,892  
2014 1,157  
2015 395  
2016 34  
2017 35  
Thereafter $ 55  
XML 90 R34.htm IDEA: XBRL DOCUMENT v2.4.0.6
Other Receivables (Tables)
 12 Months Ended
Dec. 31, 2012
Other Receivables  
Schedule of other receivables

 

 

 
   2011   2012  

Loans to customers to finance vehicle purchases

   $ 1,789   $ 4,151  

Capital lease receivables

     310     308  

Accrued customer billings

     5,860     6,934  

Fuel tax credits

     5,912     2,780  

Other

     5,730     3,635  
           

 

   $ 19,601   $ 17,808  
           
XML 91 R51.htm IDEA: XBRL DOCUMENT v2.4.0.6
Acquisitions (Details)
In Thousands, except Share data, unless otherwise specified
 12 Months Ended 0 Months Ended 4 Months Ended 12 Months Ended 0 Months Ended 12 Months Ended 0 Months Ended
Dec. 31, 2012
USD ($)
Dec. 31, 2011
USD ($)
Sep. 07, 2010
IMW
USD ($)
Dec. 31, 2010
IMW
USD ($)
Dec. 31, 2012
IMW
USD ($)
Dec. 31, 2011
IMW
USD ($)
Dec. 31, 2010
IMW
USD ($)
Sep. 07, 2010
IMW
Minimum
Sep. 07, 2010
IMW
Maximum
USD ($)
Feb. 07, 2013
IMW
IMW Notes
USD ($)
Feb. 07, 2013
IMW
IMW Notes
CAD
Jan. 31, 2011
IMW
IMW Notes
USD ($)
Sep. 07, 2010
IMW
IMW Notes
USD ($)
Dec. 31, 2012
IMW
IMW Notes
USD ($)
Dec. 31, 2012
IMW
IMW Notes
CAD
Sep. 07, 2010
IMW
Promissory notes due and payable on January 31, 2014
USD ($)
Sep. 07, 2010
IMW
Promissory notes due and payable on January 31, 2014
CAD
Sep. 07, 2010
IMW Compressors (Shanghai) Co. Ltd
USD ($)
Natural Gas Fueling Compressors                                    
Cash payment     $ 15,034                             $ 288
Common stock issued in connection with acquisition     4,017,408                              
Annual payment required                               7,500 5,000  
Amount paid                   7,500 5,000 12,500   7,500 5,000      
Cash and/or common stock required to be paid or issued on debt instrument                         7,500          
Contingent consideration                                    
Period of acquiree's future gross profits as basis for additional contingent consideration     4 years                              
Percentage of acquiree's gross profits as basis for additional contingent consideration               0.00% 23.00%                  
Aggregate contingent consideration payment                 40,000                  
Acquiree's future gross profits as basis for maximum aggregate contingent consideration                 174,000                  
Contingent consideration payment 350 2,394     350 235                        
Estimate of fair values of assets acquired and liabilities assumed                                    
Current assets     27,149                              
Property, plant and equipment     2,559                              
Identifiable intangible assets     81,400                              
Goodwill     45,049                              
Total assets acquired     156,157                              
Liabilities assumed     (25,986)                              
Total purchase price     130,171                              
Identifiable intangible assets, estimated useful lives               3 years 20 years                  
Contingent liability     9,300                              
Fair value of contingent consideration         1,516                          
Pro forma results of operations                                    
Revenue             249,093                      
Net (loss)             (7,922)                      
Basic and diluted (in dollars per share)             $ (0.12)                      
Revenue       17,795                            
Net loss       $ 319                            
XML 92 R21.htm IDEA: XBRL DOCUMENT v2.4.0.6
Commitments and Contingencies
 12 Months Ended
Dec. 31, 2012
Commitments and Contingencies  
Commitments and Contingencies

(13) Commitments and Contingencies

Environmental Matters

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

Litigation, Claims and Contingencies

        The Company may become party to various legal actions that arise in the ordinary course of its business. 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 at this time to determine the ultimate liabilities that the Company may incur resulting from any lawsuits, claims and proceedings, audits, commitments, contingencies and related matters or the timing of these liabilities, if any. If these matters were to be ultimately 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 or results of operations. However, the Company believes that the ultimate resolution of such actions will not have a material adverse affect on the Company's consolidated financial position, results of operations, or liquidity.

        On July 15, 2010, the Internal Revenue Service ("IRS") sent the Company a letter disallowing approximately $5,073 related to certain claims it made from October 1, 2006 to June 30, 2008 under the Volumetric Excise Tax Credit program. In December 2012, the Company reached an agreement with the IRS to settle the dispute for $2,057.

Operating Lease Commitments

        The Company leases facilities, including the land for its LNG production plant in Boron, California, and certain equipment under noncancelable operating leases expiring at various dates through 2038. The following schedule represents the future minimum lease obligations for all noncancelable operating leases as of December 31, 2012:

Fiscal year:

        

2013

   $ 5,617  

2014

     5,445  

2015

     5,183  

2016

     4,996  

2017

     4,702  

Thereafter

     11,956  
       

Total future minimum lease payments

   $ 37,899  
       

        Rent expense, including variable rent, totaled $6,190, $6,517, and $7,737 for the years ended December 31, 2010, 2011 and 2012, respectively.

Take-or-Pay LNG Supply Contracts

        At December 31, 2012, the Company is party to an LNG supply contract at market prices that contains minimum take or pay provisions over the term of the contract. The contract contains fixed amounts the Company must pay for any shortfall below its minimum volume requirements and also contains a variable charge that is based on the price of natural gas for the month when a shortfall occurs. The contract, which replaced a similar contract that expired in June 2011, expires in June 2014. For the years ended December 31, 2010, 2011 and 2012, the Company paid approximately $4,281, $5,034, and $3,821, respectively, under this contract. At December 31, 2012, the fixed commitments under this contract totaled approximately $2,095, $1,049 for the years ending December 31, 2013 and 2014, respectively.

        Additionally, in October 2007, the Company entered into an LNG sales agreement with Desert Gas Services (formerly known as Spectrum Energy Services, LLC) ("DGS"), to purchase, on a take-or-pay basis over a term of ten years, 45,000 gallons per day of LNG from a plant constructed by DGS in Ehrenberg, Arizona, which is near the California border. This obligation began in March 2010, and for the years ended December 31, 2010, 2011 and 2012, the Company paid approximately $4,041, $7,599, and $8,153, respectively, under the take-or-pay supply contract. The contract expires in October 2017. At December 31, 2012, the fixed commitments under this contract totaled approximately $3,058 for each of the years ending December 31, 2013 through December 31, 2016, and $2,549 for the year ended December 31, 2017.
XML 93 R26.htm IDEA: XBRL DOCUMENT v2.4.0.6
Fair Value Measurements
 12 Months Ended
Dec. 31, 2012
Fair Value Measurements  
Fair Value Measurements

(18) 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 twelve months ended December 31, 2012, the Company's financial instruments consisted of available-for-sale securities, natural gas futures contracts, debt instruments, a contingent consideration obligation, and its Series I warrants. For securities available-for-sale, the fair value is determined by the most recent trading prices available for each security or for comparable securities, and thus represent Level 2 fair value measurements. The Company uses quoted forward price curves, discounted to reflect the time value of money, to value its natural gas futures contracts which is considered to be a Level 2 fair value measurement. The Company uses projected financial results for the respective entities, discounted to reflect the time value of money, to value its contingent consideration obligations which are considered to be Level 3 fair value measurements. The fair market value of the Company's debt instruments approximated their carrying values at December 31, 2012. The Company uses the Black-Scholes model to value the Series I warrants. The Company believes the best method to approximate the 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 3.33 years as of December 31, 2012. This method has been utilized consistently in the periods presented. Given 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 determination in the table below.

        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, 2011 and December 31, 2012, respectively:

Description
  Balance at
December 31, 2011		   Level 1   Level 2   Level 3  

Assets:

                          

Available-for-sale securities(1):

                          

Certificate of deposits

   $ 10,000   $ —   $ 10,000   $ —  

Municipal bonds and notes

     19,589     —     19,589     —  

Zero coupon bonds

     712     —     712     —  

Corporate bonds

     3,028     —     3,028     —  

Liabilities:

                          

Natural gas futures contracts(2)

     2,335     —     2,335     —  

Contingent consideration obligation(3)

     5,978     —     —     5,978  

Series I warrants(4)

     11,493     —     —     11,493  

 

Description
  Balance at
December 31, 2012		   Level 1   Level 2   Level 3  

Assets:

                          

Available-for-sale securities(1):

                          

Certificate of deposits

   $ 10,021   $ —   $ 10,021   $ —  

Municipal bonds and notes

     23,650     —     23,650     —  

Corporate bonds

     4,504     —     4,504     —  

Liabilities:

                          

Natural gas futures contracts(2)

     107     —     107     —  

Contingent consideration obligation(3)

     1,516     —     —     1,516  

Series I warrants(4)

     8,102     —     —     8,102  
(1)
Included in short-term investments in the consolidated balance sheets. See note 4 for further information.

(2)
See note 10 for further information.

(3)
The current portion is included in accrued liabilities, and the long-term portion is included in other long-term liabilities in the consolidated balance sheets.

(4)
Included in other long-term liabilities in the consolidated balance sheets.

        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: Contingent Consideration
  2011   2012  

Beginning Balance

   $ 11,200   $ 5,978  

Business combinations

     —     —  

Total (gain) loss included in earnings

     (2,828 )   (4,112 )

Payments

     (2,394 )   (350 )

Transfers In/Out

     —     —  
           

Ending Balance

   $ 5,978   $ 1,516  
           

 

Liabilities: Series I Warrants
  2011   2012  

Beginning Balance

   $ 14,148   $ 11,493  

Total (gain) loss included in earnings

     (2,655 )   (3,391 )

Issuance of warrants

     —     —  

Exercise of warrants

     —     —  

Transfers In/Out

     —     —  
           

Ending Balance

   $ 11,493   $ 8,102  
           

        During the fourth quarter of 2010, the Company recorded an impairment of $1,531 of an acquired operating and maintenance contract lost in a competitive bid to a competitor. In addition, during the fourth quarter of 2010, the Company's subsidiary, DCE, expensed approximately $717 of costs related to equipment that was replaced as part of its expansion of the McCommas Bluff landfill in Dallas, Texas. During the fourth quarter of 2012, the Company recorded an impairment of $14,544 related to its investment in VPG due to a permanent decline in its value. There were no long-lived asset impairments in 2011.

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.

Contingent Consideration

        Pursuant to the terms presented in the Asset Purchase Agreement, the IMW shareholder will earn additional consideration if IMW achieves certain minimum gross profit targets in fiscal years 2011 through 2014. Therefore, the Company estimated the fair value of the contingent consideration using a discounted cash flow model that considers the payout structure based on the following inputs as of December 31, 2012:

Unobservable Input
  Range or Weighted Average

Gross profit projection

   $14,162–$32,641

Probability of reaching target gross profit

   0.0%–75.0%

Volatility of gross profit (peer group)

   14.6%–55.2% (simple average 31.4%)

Risk adjusted discount rate

   35.9%

        Significant changes in any of those inputs in isolation would result in a significant change in the fair value measurement. Generally, a positive change in the assumptions used for the probability of achieving a higher gross profit target threshold would result in a directionally similar change in the estimated fair value of the contingent consideration, and thus an increase in the associated liability. Conversely, an increase in the assumed discount rate would have a directionally opposite impact on the estimated fair value measurement of the contingent consideration, and would result in a decrease in the associated liability.

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 December 31, 2012:

Unobservable Input
  Range or Weighted Average  

Current market price of the Company's common stock

     $12.45  

Exercise price of the warrant

     $12.68  

Dividend yield

     0.00%  

Remaining term of the warrant

     3.33  

Implied volatility of the Company's common stock

     45.2%–47.2%  

Assumed discount rate

     Simple average 0.4%  

        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 warrant 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 plans to, declare dividends on its common stock, and thus, there is no directionally similar change in the estimated fair value of the warrants due to the dividend assumption.
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Summary of Significant Accounting Policies (Details 5)
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Options
      
Net Loss Per Share      
Anti-dilutive securities ( in shares) 12,083,677 10,683,303 10,433,551
Warrants
      
Net Loss Per Share      
Common stock related to the GE Warrant included in the basic and dilutive net loss per share calculation 5,000,000    
Anti-dilutive securities ( in shares) 2,130,682 2,130,682 17,130,682
Convertible notes
      
Net Loss Per Share      
Anti-dilutive securities ( in shares) 16,262,226 13,164,557  
Restricted stock units
      
Net Loss Per Share      
Anti-dilutive securities ( in shares) 1,545,000    
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Commitments and Contingencies (Tables)
 12 Months Ended
Dec. 31, 2012
Commitments and Contingencies  
Schedule of future minimum lease obligations for all noncancelable operating leases

The following schedule represents the future minimum lease obligations for all noncancelable operating leases as of December 31, 2012:

Fiscal year:

        

2013

   $ 5,617  

2014

     5,445  

2015

     5,183  

2016

     4,996  

2017

     4,702  

Thereafter

     11,956  
       

Total future minimum lease payments

   $ 37,899  
       
XML 96 R5.htm IDEA: XBRL DOCUMENT v2.4.0.6
Consolidated Statements of Comprehensive Income (Loss) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Net income (loss) $ (100,862) $ (47,455) $ (2,773)
Other comprehensive income, net of tax:      
Foreign currency translation adjustments 4,030 2,101 (1,778)
Foreign currency adjustments on intra-entity long-term investments 1,218 (1,286)  
Unrealized losses on available-for sale securities (32) (126)  
Unrecognized gains (losses) on derivatives 2,151 2,091 (4,231)
Total other comprehensive income (loss), net of tax 7,367 2,780 (6,009)
Comprehensive income (loss) (93,495) (44,675) (8,782)
Clean Energy Fuels Corp
      
Net income (loss) (101,255) (47,633) (2,516)
Other comprehensive income, net of tax:      
Foreign currency translation adjustments 4,030 2,101 (1,778)
Foreign currency adjustments on intra-entity long-term investments 1,218 (1,286)  
Unrealized losses on available-for sale securities (32) (126)  
Unrecognized gains (losses) on derivatives 2,151 2,091 (4,231)
Total other comprehensive income (loss), net of tax 7,367 2,780 (6,009)
Comprehensive income (loss) (93,888) (44,853) (8,525)
Noncontrolling Interest in Subsidiary
      
Net income (loss) 393 178 (257)
Other comprehensive income, net of tax:      
Comprehensive income (loss) $ 393 $ 178 $ (257)
XML 97 R10.htm IDEA: XBRL DOCUMENT v2.4.0.6
Acquisitions
 12 Months Ended
Dec. 31, 2012
Acquisitions  
Acquisitions

(2) Acquisitions

Natural Gas Fueling Compressors

        On September 7, 2010, the Company, acting through certain of its subsidiaries, completed its purchase of the advanced natural gas fueling compressor and related equipment manufacturing and servicing business of IMW. IMW manufactures and services advanced, non-lubricated natural gas fueling compressors and related equipment for the global natural gas fueling market. IMW is headquartered near Vancouver, British Columbia, and has other manufacturing facilities near Shanghai, China and in Ferndale, Washington, and has sales and service offices in Bangladesh, Colombia, Peru and the United States.

        In connection with the closing of the Company's acquisition of IMW, a subsidiary of the Company (the "Acquisition Subsidiary") paid an upfront cash payment of $15,034 and issued 4,017,408 shares of the Company's common stock at closing to IMW's shareholder. The issued shares were registered and available for immediate resale by the IMW shareholder. An additional $288 was paid by the Acquisition Subsidiary when the Chinese regulatory authorities subsequently approved the transfer of IMW Compressors (Shanghai) Co. Ltd. to the Acquisition Subsidiary. The Acquisition Subsidiary also issued the following promissory notes, as amended on February 1, 2011, to the IMW shareholder (collectively, the "IMW Notes"): (i) a promissory note with a principal amount of $12,500 that was paid on January 31, 2011, (ii) a promissory note with a principal amount of CAD$5,000 and $7,500 that was paid in 2012, (iii) a promissory note with a principal amount of CAD$5,000 and $7,500 that was paid on February 7, 2013, and (iv) a promissory note with a principal amount of CAD$5,000 and $7,500 that is due and payable on January 31, 2014. The Company can pay $7,500 of each IMW Note in cash and/or shares of the Company's common stock (the exact combination of cash and/or stock to be determined at the Company's option). In addition, pursuant to a security agreement executed at closing, the IMW Notes are secured by a subordinate security interest in IMW.

        IMW's former shareholder may also receive additional contingent consideration based on future gross profits earned by IMW over the four year period following the acquisition. The additional contingent consideration is subject to achieving minimum gross profit targets and will be determined based on a sliding scale that increases at certain gross profit levels. During the four-year period during which these earn-out payments may be made, the former shareholder of IMW will receive between zero and 23% of the gross profit of IMW as additional consideration, up to a maximum of $40,000 in the aggregate (which maximum would be payable if IMW achieves approximately $174,000 in gross profit over the four-year period during which these earn-out payments may be made). The IMW shareholder earned $235 for the first contingent consideration payment in 2011 and $350 for the second contingent consideration payment in 2012.

        The Company accounted for this acquisition in accordance with 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 fair value of the assets acquired and liabilities assumed:

Current assets

   $ 27,149  

Property, plant and equipment

     2,559  

Identifiable intangible assets

     81,400  

Goodwill

     45,049  
       

Total assets acquired

     156,157  

Liabilities assumed

     (25,986 )
       

Total purchase price

   $ 130,171  
       

        Management allocated approximately $81,400 of the purchase price to the identifiable intangible assets related to technology, customer relationships, non-compete agreements, and trademarks that were acquired with the acquisition. The fair value of the identifiable intangible assets will be amortized on a straight-line basis over their estimated useful lives ranging from three to twenty years. In addition, management allocated $45,049 to goodwill as part of the acquisition and recorded a contingent liability of $9,300 related to the additional contingent consideration described above. Under FASB authoritative guidance, the Company is required to adjust the value of the contingent consideration for this acquisition in the statement of operations as the value of the obligation changes each reporting period. As of December 31, 2012, the fair value of the contingent consideration was approximately $1,516.

        The results of operations of IMW have been included in the Company's consolidated financial statements since September 7, 2010.

        The following table presents the Company's unaudited pro forma results of operations for the year ended December 31, 2010 as if the acquisition had occurred at on January 1, 2010. The pro forma financial data for the period presented includes adjustments for the following: (i) elimination of intercompany transactions (ii) recording the additional amortization expense from the identifiable intangible assets (iii) adjusting the estimated tax provision of the pro forma combined results; (iv) US GAAP conversion adjustments and (v) the issuance of the Company's common stock as part of the acquisition. The Company prepared the pro forma financial information for the combined entities for comparative purposes only, and it is not indicative of what actual results would have been if the acquisition had taken place on January 1, 2010, or of future results.

 
   For the year ended
December 31, 2010		  

Revenue

   $ 249,093  

Net (loss)

     (7,922 )

(Loss) per share:

        

Basic and diluted

   $ (0.12 )

        For the period from September 7, 2010 through December 31, 2010, IMW contributed approximately $17,795 and $319, respectively, to the Company's revenue and net loss.

Liquefied Natural Gas Station Construction

        On December 15, 2010, the Company acquired Northstar, a leading provider of design, engineering, construction and maintenance services for LNG and liquefied to compressed ("LCNG") fueling stations. The purchase price primarily consisted of a closing cash payment in the amount of $7,414. The remaining consideration consists of five annual payments in the amount of $700 each commencing on the first anniversary of the closing date, and up to $4,000 in retention bonuses to certain key employees to be paid in four annual installments commencing on the first anniversary of the closing date.

        The following table summarizes the estimated fair values of the assets acquired and liabilities assumed as of December 15, 2010:

Current assets

   $ 4,434  

Property, plant and equipment

     941  

Identifiable intangible assets

     3,350  

Goodwill

     5,228  
       

Total assets acquired

     13,953  

Liabilities assumed

     (3,648 )
       

Total purchase price

   $ 10,305  
       

        Management allocated $2,250 of the purchase price to the identifiable intangible assets related to non-compete agreements, customer relationships, and backlog. The fair value of these identifiable intangibles will be amortized on a straight-line basis over their estimated useful lives ranging from one to ten years. The Company also allocated $1,100 of the purchase price to trademarks, which management believes has an indefinite useful life. In addition, management allocated $5,228 to goodwill as part of the acquisition.

        The results of Northstar's operations have been included in the Company's consolidated financial statements since December 15, 2010. Pro forma financial information has been excluded as Northstar's historical results of operation are immaterial to that of the Company.

Operating and Maintenance Contracts

        In May and June 2009, the Company acquired four compressed natural gas operations and maintenance services contracts for $5,645 in cash. The Company recorded $537 to tangible assets and $5,108 of intangible assets related to customer relationships, which are being amortized over their expected lives of eight years. The results of operations of the acquired contracts are included in the Company's consolidated financial statements from their acquisition dates forward, which are May 2009 for two of the contracts and June 2009 for the remaining two contracts. In addition, as part of the acquisition, the Company became the custodian of certain customer-owned inventories that it is required to replenish when the contracts expire. The customer-owned inventory was valued by the Company's as an asset at $986 with a corresponding balance of $986 recorded as a liability on the acquisition dates of the contracts. During 2010, the Company recorded a charge of $1,531 related to the impairment of an intangible asset originally recorded with this acquisition.

Vehicle Conversion

        On October 1, 2009, the Company purchased all the outstanding shares of BAF Technologies, Inc. ("BAF") under a stock purchase agreement for a total purchase price of $11,567, consisting of cash of $4,717, forgiveness of debt of $3,790, and net liabilities assumed of $3,060. BAF shareholders earned additional consideration of $2,159 in 2011 because BAF had achieved certain gross profit targets in 2010. The BAF shareholders did not receive any additional consideration for 2011, which was the end of the contingent consideration period.

        The Company allocated approximately $10,660 of the purchase price to the identifiable intangible assets related to customer relationships, engine certifications and trademarks that were acquired with the acquisition. The fair values of the identifiable intangible assets are being amortized on a straight-line basis over their estimated useful lives of 1.5 to 8 years. In addition, the Company allocated $774 to goodwill as part of the acquisition.

        On February 25, 2011 (the "Closing Date"), the Company paid $1,200 for a 19.9% interest in ServoTech Engineering, Inc. ("ServoTech"), a company that provides, among other services, design and engineering services for natural gas fueling systems. In connection with the investment, the Company was granted an option to purchase the remaining 80.1% of ServoTech for $2,800 (the "Exercise Price") during the 15 month period following the Closing Date (the "Purchase Option"). On April 30, 2012, the Company exercised the Purchase Option, paid 50% of the Exercise Price, or $1,400, in cash on that date, and paid the remaining $1,400 of the Exercise Price in cash on October 31, 2012. Through April 30, 2012, the Company accounted for its interest in ServoTech using the equity method of accounting as the Company had the ability to exercise significant influence over ServoTech's operations.

        The Company accounted for this acquisition in accordance with the authoritative guidance for business combinations in stages. The Company re-measured its previously held equity interest in ServoTech at fair value as of April 30, 2012 (the acquisition date) resulting in no gain or loss, and recognized the assets acquired and the liabilities assumed, measured at their fair values, as of the date of acquisition. The following table summarizes the estimated fair values of the assets acquired and liabilities assumed as of the acquisition date:

Current assets

   $ 2,655  

Property & equipment

     239  

Identifiable intangible assets

     3,913  
       

Total assets acquired

     6,807  

Current liabilities assumed

     (2,807 )
       

Total purchase price

   $ 4,000  
       

        The Company identified intangible assets with estimated fair value of $3,913 related to certain customer contracts, the facility lease, and technology. The fair value of the identified intangible assets will be amortized on a straight-line basis over their estimated useful lives, ranging from two to seven years.

        The results of ServoTech's operations have been included in the Company's consolidated financial statements since April 30, 2012. The historical results of ServoTech's operations were not material to the Company's financial position or historical results of operations.
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Investment in Other Entities (Details) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended 3 Months Ended 6 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Dec. 31, 2012
VPG
Jun. 30, 2012
VPG
Cost method investments          
Payment for investments $ 1,437 $ 4,712 $ 427   $ 1,437
Investment amount $ 14,544     $ 14,544  
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Income Taxes (Details 3) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
Income Taxes      
Valuation allowance $ 81,257 $ 53,329  
Net change in valuation allowance after adjustments between current and deferred tax assets 27,928 12,210 5,127
Undistributed earnings of non-U.S. subsidiaries 2,400    
Unrecognized tax benefits, which if recognized, would primarily affect the effective tax rate 515 305 50
Reconciliation of the total amounts of unrecognized tax benefits      
Unrecognized tax benefit at the beginning of the period 305 50  
Gross increases-tax positions in prior years 260 255  
Gross (decreases)-tax positions in prior years (50)    
Unrecognized tax benefit at the end of the period 515 305 50
Additional information on income tax      
Interest accrued $ 21 $ 6 $ 6
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Subsequent Events
 12 Months Ended
Dec. 31, 2012
Subsequent Events  
Subsequent Events

(19) Subsequent Events

        On January 2, 2013, the American Taxpayer Relief Act was signed into law which extended VETC through December 31, 2013 and made it retroactive to January 1, 2012. Such credits for 2012 are estimated to be approximately $20,800, which will be recognized during the first quarter of 2013.

        The Company has entered into an agreement to sell its ownership interest in Peru JV for approximately $6,100 after receiving a dividend distribution of approximately $1,027. The Company expects to close the sale by March 31, 2013.

        In January and February 2013, $4,030 of principal and accrued interest under an SLG Note was converted by the holder into 268,664 shares of the Company's common stock.
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Supplier Concentrations (Details) (Natural gas expense, Supplier concentration)
 12 Months Ended
Dec. 31, 2012
Dec. 31, 2011
Dec. 31, 2010
LNG sales | Williams Gas Processing Company
      
Supplier Concentrations      
Concentration risk (as a percent) 8.00% 9.00% 9.00%
LNG sales | Shell Energy
      
Supplier Concentrations      
Concentration risk (as a percent) 31.00% 30.00% 31.00%
CNG operations | SoCal Gas Company and San Diego Gas and Electric
      
Supplier Concentrations      
Concentration risk (as a percent) 16.00% 16.00% 17.00%
XML 104 R38.htm IDEA: XBRL DOCUMENT v2.4.0.6
Derivative Transactions (Tables)
 12 Months Ended
Dec. 31, 2012
Derivative Transactions  
Schedule of notional amounts and weighted-average fixed prices per gasoline gallon equivalent of the Company's natural gas futures contracts

The following table presents the notional amounts and weighted average fixed prices per gasoline gallon equivalent of the Company's natural gas futures contracts as of December 31, 2012:

 
   Gallons   Weighted
Average Price
Per Gasoline
Gallon
Equivalent		  

2013

     1,140,000   $ 0.53  
XML 105 R20.htm IDEA: XBRL DOCUMENT v2.4.0.6
Income Taxes
 12 Months Ended
Dec. 31, 2012
Income Taxes  
Income Taxes

(12) Income Taxes

        The components of income (loss) before income taxes for the years ended December 31, 2010, 2011, and 2012 are as follows:

 
   2010   2011   2012  

U.S. 

   $ (6,048 ) $ (30,002 ) $ (91,608 )

Foreign

     1,839     (18,156 )   (7,960 )
               

 

   $ (4,209 ) $ (48,158 ) $ (99,568 )
               

        The provision (benefit) for income taxes consists of the following:

 
   2010   2011   2012  

Current:

                    

Federal

   $ (1,753 ) $ 206   $ 269  

State

     255     296     302  

Foreign

     117     396     (61 )
               

Total current

     (1,381 )   898     510  

Deferred:

                    

Federal

     (4,361 )   (8,012 )   (20,646 )

State

     (966 )   (1,724 )   (3,445 )

Foreign

     145     (4,075 )   (3,053 )

Change in valuation allowance

     5,127     12,210     27,928  
               

Total deferred

     (55 )   (1,601 )   784  
               

Total

   $ (1,436 ) $ (703 ) $ 1,294  
               

        Income tax expense (benefit) for the years ended December 31, 2010, 2011 and 2012 differs from the "expected" amount computed using the federal income tax rate of 35% as a result of the following:

 
   2010   2011   2012  

Computed expected tax expense (benefit)

   $ (1,473 ) $ (16,855 ) $ (34,849 )

State and local taxes, net of federal benefit

     174     202     121  

Nondeductible expenses

     (2,615 )   3,073     5,194  

Tax rate differential on foreign earnings

     (580 )   5,273     (717 )

Refund of alternative minimum taxes

     (1,323 )   —     —  

Tax credits

     (875 )   (834 )   —  

Other

     129     (148 )   (1,563 )

Change in valuation allowance

     5,127     8,586     33,108  
               

Total tax expense (benefit)

   $ (1,436 ) $ (703 ) $ 1,294  
               

        Deferred tax assets and liabilities result from differences between the financial statement carrying amounts and the tax bases of existing assets and liabilities. The tax effect of temporary differences that give rise to deferred tax assets and liabilities as of December 31, 2011 and 2012 are as follows:

 
   2011   2012  

Deferred tax assets:

              

Accrued expenses

   $ 1,163   $ 2,303  

Sales-type leases

     212     500  

Alternative minimum tax and general business credits

     3,470     3,297  

Derivative loss

     2,363     1,831  

Stock option expense

     11,611     15,259  

Other

     1,223     644  

Loss carryforwards

     55,212     79,819  
           

Total deferred tax assets

     75,254     103,653  

Less valuation allowance

     (53,329 )   (81,257 )
           

Net deferred tax assets

     21,925     22,396  
           

Deferred tax liabilities:

              

Depreciation and amortization—domestic

     (19,724 )   (20,291 )

Depreciation and amortization—foreign

     (928 )   (1,045 )

Partnership income

     (1,500 )   (2,071 )
           

Total deferred tax liabilities

     (22,152 )   (23,407 )
           

Net deferred tax assets (liabilities)

   $ (227 ) $ (1,011 )
           

        At December 31, 2012, the Company had federal and state net operating loss carryforwards of approximately $190,584 and $184,531, respectively. The Company's federal net operating loss carryforward will expire beginning in 2026. The Company's state net operating loss carryforwards begin expiring in 2013. At December 31, 2012, the Company also had federal and state capital loss carryforwards of approximately $14,544, which will expire in 2017. The Company also has a foreign loss carryforward of approximately $27,054 at December 31, 2012, which will expire beginning in 2017. Due to the change of ownership provisions of Internal Revenue Code Section 382, utilization of a portion of the Company's net operating loss and tax credit carryforwards may be limited in future periods.

        In assessing the realizability of the net deferred tax assets, management considers whether it is more likely than not that some or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers projected future taxable income and tax planning strategies in making this assessment. As of December 31, 2011 and 2012, the Company provided a valuation allowance of $53,329, and $81,257, respectively, to reduce the net deferred tax assets due to uncertainty surrounding the realizability of these assets. The net change in the valuation allowance for the years ended December 31, 2010, 2011, and 2012 was $5,127, $12,210, and $27,928, respectively, after adjustments between current and deferred taxes.

        As of December 31, 2012, the Company has not provided deferred U.S. income taxes or foreign withholding taxes on temporary differences of approximately $2,400 resulting from earnings of certain non-U.S. subsidiaries which are permanently reinvested outside the U.S. Unrecognized deferred taxes on remittance of these funds are not expected to be material.

        On January 1, 2007, the Company adopted certain accounting guidance that clarifies the accounting for uncertain tax positions. This guidance requires that the Company recognizes the impact of a tax position in its financial statements if the position is more likely than not of being sustained upon examination, based on the technical merits of the position. The impact of the adoption of this guidance was immaterial to the Company's consolidated financial statements. The total amount of unrecognized tax benefits as of December 31, 2010, 2011, and 2012 were $50, $305, and $515, respectively, which if recognized, would primarily affect the effective tax rate in future periods.

        The following is a tabular reconciliation of the total amounts of unrecognized tax benefits for the years ended December 2011 and 2012:

Unrecognized tax benefit—December 31, 2010

   $ 50  

Gross increases—tax positions in prior years

     255  

Gross (decreases)—tax positions in prior years

     —  
       

Unrecognized tax benefit—December 31, 2011

     305  

Gross increases—tax positions in prior years

     260  

Gross (decreases)—tax positions in prior years

     (50 )
       

Unrecognized tax benefit—December 31, 2012

   $ 515  
       

        FASB authoritative guidance requires the Company to accrue interest and penalties where there is an underpayment of taxes based on the Company's best estimate of the amount ultimately to be paid. The Company's policy is to recognize interest accrued related to unrecognized tax benefits and penalties as income tax expense. During each of the years ended December 31, 2010, 2011 and 2012, the Company accrued interest of $6, $6, and $21, respectively. No penalties have been accrued by the Company.

        The Company is subject to taxation in the United States and various states and foreign jurisdictions. The Company's tax years for 2008 through 2011 are subject to examination by various tax authorities. The Company is no longer subject to U.S. examination for years before 2009, and state examinations for years before 2008.

        A number of years may elapse before an uncertain tax position is finally resolved. It is often difficult to predict the final outcome or the timing of resolution of any particular uncertain tax position, but the Company believes that its reserves for income taxes reflect the most probable outcomes. The Company adjusts the reserve, as well as the related interest, in light of changing facts and circumstances. Settlement of any particular position would usually require the use of cash and result in the reduction of the related reserve, or there could be a change in the amount of the Company's net operating loss. The resolution of a matter would be recognized as an adjustment to the provision for income taxes and the effective tax rate in the period of resolution. The Company does not expect that any of its uncertain tax positions will reverse within the next twelve months.