UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT
OF 1934
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT
OF 1934
For the fiscal year ended: December 31, 2019
or
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 or organization)
33-0968580
(IRS Employer Identification No.)
4675 MacArthur Court, Suite 800, Newport Beach, CA 92660
(Address of principal executive offices, including zip code)
(949) 437-1000
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Trading Symbol(s)
Name of each exchange on which registered
Common stock, $0.0001 par value per share
CLNE
The Nasdaq Stock Market LLC
(Nasdaq Global Select Market)
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 No
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 No
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the
preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past
90 days. Yes No
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-
T (§229.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes No
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging
growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the
Exchange Act.
Large accelerated filer
Accelerated filer
Non-accelerated filer
Smaller reporting company Emerging growth company
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised
financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes No
The aggregate market value of the voting stock held by non-affiliates of the registrant as of June 28, 2019, the last business day of the registrant’s most recently
completed second fiscal quarter, was approximately $535,652,621 based on the closing price of the registrant’s common stock of $2.67 per share on that date. The
treatment of persons as affiliates of the registrant for purposes of this calculation is not, and shall not be considered, a determination as to whether any such person is an
affiliate of the registrant for any other purpose.
As of March 4, 2020, there were 205,583,627 shares of the registrant’s common stock, par value $0.0001 per share, issued and outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant’s definitive proxy statement for its 2020 annual meeting of stockholders are incorporated by reference in Part III of this report.
Clean Energy Fuels Corp.
Annual Report on Form 10-K
For the Fiscal Year Ended December 31, 2019
TABLE OF CONTENTS
Cautionary Note Regarding Forward-Looking Statements
Part I
Item 1.
Item 1A.
Item 1B.
Item 2.
Item 3.
Item 4.
Part II
Item 5.
Business
Risk Factors
Unresolved Staff Comments
Properties
Legal Proceedings
Mine Safety Disclosures
Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of
Equity Securities
Item 6.
Item 7.
Item 7A.
Item 8.
Item 9.
Item 9A.
Item 9B.
Selected Financial Data
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Quantitative and Qualitative Disclosures About Market Risk
Financial Statements and Supplementary Data
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
Controls and Procedures
Other Information
Part III
Item 10.
Item 11.
Item 12.
Directors, Executive Officers and Corporate Governance
Executive Compensation
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder
Matters
Item 13.
Item 14.
Certain Relationships and Related Transactions and Director Independence
Principal Accountant Fees and Services
Part IV
Item 15.
Item 16.
Exhibits and Financial Statement Schedules
Form 10-K Summary
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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS
This annual report on Form 10-K contains “forward-looking statements” within the meaning of Section 27A of the
Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as
amended (the “Exchange Act”). Forward-looking statements are statements other than historical facts. These statements
relate to future events or circumstances or our future performance, and they are based on our current assumptions,
expectations and beliefs concerning future developments and their potential effect on our business. In some cases, you can
identify forward-looking statements by the following words: “if,” “may,” “might,” “shall,” “will,” “can,” “could,”
“would,” “should,” “expect,” “intend,” “plan,” “goal,” “objective,” “initiative,” “anticipate,” “believe,” “estimate,”
“predict,” “project,” “forecast,” “potential,” “continue,” “ongoing” or the negative of these terms or other comparable
terminology, although the absence of these words does not mean that a statement is not forward-looking. The forward-
looking statements we make in this report include statements about, among other things:
• The willingness of fleets and fleet vehicle operators to adopt natural gas vehicles, particularly in light of operators’
competing general business concerns and possible lack of demand for such adoption from their customers and
drivers;
• Potential adoption of government policies or programs or increased publicity or popular sentiment in favor of
vehicles or vehicle fuels other than natural gas, including long-standing support for gasoline and diesel-powered
vehicles and growing support for electric and hydrogen-powered vehicles;
• Our expectations regarding the market’s perception of the benefits of conventional natural gas and renewable
natural gas (“RNG”) relative to gasoline and diesel and other alternative vehicle fuels, including with respect to
factors such as supply, cost savings, environmental benefits and safety;
• Projections regarding natural gas vehicle cost, fuel usage, availability, quality, safety, convenience (to fuel and
service), design, performance, and operator perception with respect to these factors, generally and in our key
customer markets and relative to comparable vehicles powered by other fuels;
• Our expectations regarding the development, production, cost, availability, performance, sales and marketing and
reputation of natural gas engines that are well-suited for the vehicles used in our key customer markets, including
heavy-duty trucks and other fleets;
• Future supply, demand, use and prices of crude oil, gasoline, diesel, natural gas and other vehicle fuels, such as
electricity, hydrogen, renewable diesel, biodiesel and ethanol;
• Expected rates and levels of adoption of RNG, compressed natural gas (“CNG”) and liquefied natural gas
(“LNG”) as a vehicle fuel, and our ability to capture a significant share of these markets if and when they grow;
• Our expectations regarding the customer and geographic markets that are well-suited for, and show the most
promise for adoption of, natural gas as a vehicle fuel;
• Our ability to implement our business plans and their level of success, including, among others, our goal of fueling
more natural gas heavy-duty trucks and our recently launched Zero Now truck financing program designed to
facilitate our achievement of this objective;
• The competitive environment in which we operate, including predictions of increasing competition in the market
for vehicle fuels generally, and the nature and impact of competitive developments in this market, including
improvements in or perceived advantages of non-natural gas vehicle fuels or engines powered by these fuels;
• The availability and effect on our business of environmental, tax or other government regulations, programs or
incentives that promote natural gas or other alternatives as a vehicle fuel, such as, for instance, a federal alternative
fuels tax credit (“AFTC”) and the programs under which we generate credits by selling conventional natural gas
and RNG as a vehicle fuel, including Renewable Identification Numbers (“RINs” or “RIN Credits”) under the
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federal Renewable Fuel Standard (“RFS”) Phase 2 and credits under the California and Oregon Low Carbon Fuel
Standards (collectively, “LCFS Credits”);
• The impact of, or potential for changes to, emissions requirements applicable to vehicles powered by gasoline,
diesel, natural gas or other vehicle fuels, as well as emissions and other environmental regulations, pressures and
bans on crude oil, fueling stations and drilling, production, importing or transportation methods, distribution and
fueling stations for these fuels;
• Developments in our products and services offering, including any new business activities we may pursue in the
future;
• The success and importance of any acquisitions, divestitures, investments or other strategic relationships or
transactions;
• The potential impact on our debt instruments and our business of developments regarding LIBOR, including the
potential phasing out of this metric;
• General political, regulatory, economic and market conditions;
• Our need for and ability to access additional capital to fund our business or repay our debt, through selling assets
or pursuing equity, debt or other types of financing;
• Our expectations regarding our liquidity, including our projected cash balances, expense levels, capital
expenditures and other funding requirements;
• Our expectations regarding our operating performance, including trends in our business and our industry that may
impact our future results;
• Predictions about the effect on our business of potential operational events, including, among other things, any
changes to our management team; any IT or cybersecurity breaches; any equipment defects, malfunctions, failures
and misuses; or any severe weather events that effect our station construction or other activities;
• The outcome and impact on our liquidity, performance and reputation of any pending or future government
actions, audits or other legal proceedings; and
• The impact of the above factors and other future events on the market price and trading volume of our common
stock.
The preceding list is not intended to be an exhaustive list of all of the topics addressed by our forward-looking
statements. Although the forward-looking statements we make reflect our good faith judgment based on available
information, they are only predictions of future events and conditions. Accordingly, our forward-looking statements
involve known and unknown risks, uncertainties and other factors that may cause our or our industry’s actual results, levels
of activity, performance or achievements to be materially different from any future results, levels of activity, performance
or achievements expressed or implied by our forward-looking statements. Factors that might cause or contribute to such
differences include, among others, those discussed in Item 1A. Risk Factors of this report, as such factors may be amended,
supplemented or superseded from time to time by other reports we file with the Securities and Exchange Commission (the
“SEC”). In addition, we operate in a competitive and rapidly evolving industry in which new risks emerge from time to
time, and it is not possible for us to predict all of the risks we may face, nor can we assess the impact of all factors on our
business or the extent to which any factor or combination of factors could cause actual results to differ from our
expectations. As a result of these and other potential risks and uncertainties, our forward-looking statements should not be
relied on or viewed as guarantees of future events or conditions.
All of our forward-looking statements speak only as of the date they are made and, except as required by law, we
undertake no obligation to update publicly any forward-looking statements for any reason, including to conform these
statements to actual results or to changes in our expectations. You should, however, review the factors and risks we
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describe in the reports we will file from time to time with the SEC for the most recent information about our forward-
looking statements and the risks and uncertainties related to these statements.
We qualify all of our forward-looking statements by this cautionary note.
* * * * * * *
Unless the context indicates otherwise, all references to “Clean Energy,” our “Company,” “we,” “us,” or “our” in
this report refer to Clean Energy Fuels Corp., together with its majority and wholly owned subsidiaries.
We own registered or unregistered trademark or service mark rights to Redeem™, NGV Easy Bay™, Clean Energy™,
Clean Energy Renewables™, Zero Now, and Clean Energy Cryogenics™. Although we do not use the “®” or “™” symbol
in each instance in which one of our trademarks appears in this report, this should not be construed as any indication that
we will not assert our rights thereto to the fullest extent under applicable law. Any other service marks, trademarks and
trade names appearing in this report are the property of their respective owners.
Investors and others should note that we disseminate information to the public about our Company, our products,
services and other matters through various channels, including our website (www.cleanenergyfuels.com), SEC filings,
press releases, public conference calls and webcasts, in order to achieve broad, non-exclusionary distribution of
information to the public. We encourage investors and others to review the information we make public through these
channels, as such information could be deemed to be material information.
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Item 1. Business.
Overview
PART I
We are North America’s leading provider of the cleanest fuel for the transportation market, based on the number of
stations operated and the amount of gasoline gallon equivalents (“GGEs”) of RNG, CNG and LNG delivered. Through
our sales of Redeem™ RNG, which is derived from biogenic methane produced by the breakdown of organic waste, we
help thousands of vehicles, from airport shuttles to city buses to waste and heavy-duty trucks, to reduce their amount of
climate-harming greenhouse gas by at least 70% and up to 300% depending on the source of the RNG feedstock. Redeem
RNG is delivered as CNG and LNG; sales of our Redeem RNG have increased dramatically, from 13.0 million GGEs in
2013 (the year we introduced Redeem RNG to the vehicle fuel market) to 143.3 million GGEs in 2019.
Our principal business is supplying RNG, CNG and LNG for medium and heavy-duty vehicles and providing
operation and maintenance (“O&M”) services for public and private vehicle fleet customer stations. As a comprehensive
solution provider, we also design, build, operate and maintain fueling stations; sell and service natural gas fueling
compressors and other equipment used in CNG stations and LNG stations; offer assessment, design and modification
solutions to provide operators with code-compliant service and maintenance facilities for natural gas vehicle fleets;
transport and sell CNG and LNG via “virtual” natural gas pipelines and interconnects; procure and sell RNG; sell tradable
credits we generate by selling RNG and conventional natural gas as a vehicle fuel, including RIN Credits and LCFS
Credits; help our customers acquire and finance natural gas vehicles; and obtain federal, state and local tax credits, grants
and incentives. In addition, before March 31, 2017, we produced RNG at our own production facilities (which we sold,
along with certain of our other RNG production assets to BP Products North America (“BP”), in a transaction we refer to
as the “BP Transaction”), and before December 29, 2017, we manufactured natural gas fueling compressors and other
equipment used in CNG stations (which we combined with SAFE S.p.A., the natural gas fueling compressor subsidiary of
Landi Renzo S.p.A. (“LR”) in a newly formed company, SAFE&CEC S.r.l., in a transaction we refer to as the “CEC
Combination”).
We serve fleet vehicle operators in a variety of markets, including heavy-duty trucking, airports, refuse, public transit,
industrial and institutional energy users, and government fleets. We believe these fleet markets will continue to present a
growth opportunity for natural gas vehicle fuel for the foreseeable future. As of December 31, 2019, we serve over 1,000
fleet customers operating over 48,000 natural gas vehicles, and we own, operate or supply approximately 550 natural gas
fueling stations in 41 states in the United States and four provinces in Canada. We estimate our number of stations is
approximately three times the number of CNG fueling stations operated by our largest competitor in today’s market, and
we believe our natural gas fueling operations cover more states and provinces than any of our competitors. We believe we
are the only company in the United States or Canada that provides RNG, CNG and LNG vehicle fuel on a significant scale.
Market for RNG, CNG and LNG as a Vehicle Fuel
Natural Gas Vehicles for America (“NGV America”) estimates that, as of December 31, 2019, there were
approximately 1,750 natural gas fueling stations in the United States and more than 175,000 natural gas vehicles on
American roads.
We believe the following benefits of natural gas fuel drive the development of the market for RNG, CNG and LNG
as a vehicle fuel in the United States:
Cleaner. RNG vehicle fuel has enhanced environmental benefits relative to gasoline and diesel vehicle fuels. The
California Air Resources Board (“CARB”) has determined that RNG reduces the amount of climate-harming greenhouse
gas by at least 70% and up to 300%, depending on the RNG feedstock, compared to gasoline and diesel. Simply put, RNG
can be a carbon negative vehicle fuel
In addition, natural gas produces fewer carbon dioxide emissions than any other fossil fuel when burned. CARB has
concluded that vehicles fueled by conventional natural gas produce between 12% and 22% fewer greenhouse gas emissions
than comparable gasoline and diesel fueled vehicles.
5
Further, natural gas engines now commercially available for heavy-duty, regional-haul, refuse, transit and vocational
applications have been certified to CARB and the U.S. Environmental Protection Agency (“EPA”) optional low NOx
emission standard of 0.02 g/bhp-hr. This means that these engines emit 90% less smog-forming nitrogen oxides (also
known as “NOx”) than the existing regulatory standards, making them the lowest certified ultra-low NOx emission engines
in North America. We therefore believe vehicles equipped with ultra-low NOx engines that are fueled with RNG are the
cleanest commercially available vehicles in North America (in terms of greenhouse gas emissions and NOx).
We expect our sales of Redeem RNG and conventional natural gas to grow as more companies look to operate in an
increasingly sustainable way. In addition to pressure from politicians, regulators and non-governmental organizations, the
investment community has dramatically stepped up demands on companies to diminish their contributions to climate
change. We believe that RNG is the best tool available today to reduce climate-harming greenhouse gas and meet
sustainability objectives.
By way of example, in January 2020, Microsoft announced that it will be carbon negative by 2030, and that by 2050
it will remove from the environment all the carbon Microsoft has emitted either directly or by electrical consumption since
it was founded in 1975. We believe that by 2027, Microsoft can be carbon negative and offset all of its post-1975 carbon
emissions if it adopts 100% carbon negative RNG.
Domestic and Plentiful Supply. Technological advances in production have unlocked supplies of RNG and vast
conventional natural gas reserves. The United States has proven, abundant and growing reserves of natural gas, and
produces the highest volume of natural gas in the world.
Less Expensive. The cost of RNG, CNG and LNG in the United States is less than the cost of crude oil on an energy
equivalent basis. Based on projections from the U.S. Energy Information Administration, we believe RNG, CNG and LNG
will remain cheaper than gasoline and diesel for the foreseeable future. In addition, because the price of the commodity
makes up a smaller portion of the cost of a GGE of RNG, CNG or LNG relative to the commodity portion of the cost of a
GGE of diesel or gasoline, the price of a GGE of RNG, CNG or LNG is less sensitive to increases in the underlying
commodity cost.
Safer. As reported by NGV America, RNG, CNG and LNG are relatively safer than gasoline and diesel because
they dissipate into the air when spilled or in the event of a vehicle accident. When released, RNG, CNG and LNG are also
less combustible than gasoline or diesel because they ignite only at relatively high 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,
burst pressure and crash testing, according to the U.S. Department of Transportation National Highway Traffic Safety
Administration. RNG, CNG and LNG are stored in above-ground tanks and therefore will not contaminate soil or
groundwater in the event of a spill or leak.
Natural Gas Vehicles
Natural gas vehicles use internal combustion engines similar to those used in gasoline- or diesel-powered vehicles,
and the acceleration and other performance characteristics of natural gas vehicles are also similar to those of gasoline- or
diesel-powered vehicles of the same weight and engine class. Natural gas vehicles, whether they run on RNG, CNG or
LNG, are refueled using a hose and nozzle that makes an airtight seal with the vehicle’s fuel tank.
Natural gas vehicles have engines specially tuned to run on natural gas fuels, which has a higher octane number than
gasoline or diesel, and fuel tanks and lines specially designed to hold RNG, CNG and LNG and deliver it to the vehicle’s
engine. These special features, including principally the fuel tanks that hold RNG, CNG and LNG, cause natural gas
vehicles to typically cost more than comparable gasoline- or diesel-powered vehicles. Additionally, for heavy-duty
vehicles, spark-ignited natural gas vehicles operate more quietly than comparable diesel-powered vehicles. Due to
improvements in diesel engine technology, natural gas vehicles may be somewhat less efficient than diesel vehicles in
terms of miles per gallon, depending upon the application.
Virtually any car, truck, bus or other vehicle is capable of being manufactured or modified to run on natural gas. Many
types and models of heavy-, medium- and light-duty natural gas vehicles and engines are available in the United States
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and Canada, including, among others, long-haul tractors, refuse trucks, regional tractors, transit buses, ready-mix trucks,
delivery trucks, vocational work trucks, school buses, shuttles, passenger sedans, pickup trucks and cargo and passenger
vans. We expect additional types and models of natural gas vehicles to become available if adoption of RNG and
conventional natural gas as a vehicle fuel becomes more widespread in the United States.
Our Products, Services and Other Business Activities
Our principal products, services and other business activities are described below. Information about the revenue we
receive from these activities is discussed in this report in Item 7. Management’s Discussion and Analysis of Results of
Operations and Financial Condition.
CNG Sales. CNG is RNG and conventional natural gas that is compressed and dispensed in gaseous form. CNG is
typically delivered by obtaining natural gas from local utilities or third-party marketers and then compressing and storing
it at a fueling station and dispensing it directly into a vehicle. Some of the natural gas we obtain from third parties for CNG
sales is purchased under take-or-pay contracts that require us to purchase minimum volumes of natural gas.
We sell CNG for use as a vehicle fuel through fueling stations located on our customers’ properties and through our
network of public access fueling stations. Our CNG vehicle fuel sales are made primarily through contracts with our
customers. Under many of these contracts, pricing is determined on an index-plus basis, which is calculated by adding a
margin and delivery cost to the local index or utility price for natural gas. As a result, CNG vehicle fuel sales determined
by an index-plus methodology increase or decrease as a result of an increase or decrease in the cost of natural gas, including
transportation charges, utility costs and other fees. The remainder of our CNG vehicle fuel sales are made on a per fill-up
basis at prices we set at public access fueling stations based on prevailing market conditions.
Through our subsidiary NG Advantage, LLC (“NG Advantage”), we also transport and sell CNG for non-vehicle
purposes via virtual natural gas pipelines and interconnects. NG Advantage transports CNG to industrial and institutional
energy users that do not have direct access to natural gas pipelines. NG Advantage also transports CNG between pipelines
for customers that desire to take advantage of commodity price differences. NG Advantage uses a fleet of 113 high-
capacity tube trailers to transport CNG.
LNG Production and Sales. LNG is RNG and conventional natural gas that is cooled at a liquefaction facility to
approximately -260 degrees Fahrenheit until it condenses into a liquid. We obtain LNG from our own liquefaction plants
and from third-party suppliers. We own and operate LNG liquefaction plants near Boron, California and Houston, Texas,
which we call the “Boron Plant” and the “Pickens Plant” respectively. The Boron Plant can produce 60.0 million gallons
of LNG per year and has a dual tanker trailer loading system and a 1.8 million gallon storage tank that can hold up to
1.5 million usable gallons. The Pickens Plant can produce 35.0 million gallons of LNG per year and includes a tanker
trailer loading system and a 1.0 million gallon storage tank that can hold up to 840,000 usable gallons. In 2019, we
purchased 14.5% of our LNG from third-party suppliers and we produced the remainder of our LNG at our plants.
We sell LNG for use as a vehicle fuel on a bulk basis to fleet customers, who often own and operate their fueling
stations, and through our network of public access fueling stations. We deliver LNG via our fleet of 74 tanker trailers to
fueling stations, where it is stored and then dispensed in liquid form into vehicles. We contract with third parties to provide
tractors and drivers. The need to liquefy and transport LNG generally causes LNG to cost more than CNG. We sell LNG
through supply contracts that are priced on an index-plus basis, such that LNG sales under these contracts increase or
decrease as a result of an increase or decrease in the cost of natural gas. We also sell LNG vehicle fuel on a per fill-up
basis at prices we set at public access fueling stations based on prevailing market conditions. Additionally, we sell LNG
for non-vehicle purposes, including to customers who use LNG in oil fields, and for utility, industrial, marine and rail
applications.
RNG Sales. RNG is delivered as CNG or LNG. It is produced from organic waste at landfills, animal waste digesters,
wastewater treatment plants and other locations. RNG is injected into natural gas pipelines, which allows RNG to be
transported to vehicle fueling stations where it can be compressed and dispensed as CNG, and to LNG liquefaction
facilities where it is converted to LNG. We purchase RNG from BP and other third-party producers, and we sell that RNG
for vehicle fuel use through our fueling infrastructure under the brand name Redeem™.
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Sales of RINs and LCFS Credits. We generate RIN Credits when we sell RNG for use as a vehicle fuel in the United
States, and we generate LCFS Credits when we sell RNG and conventional natural gas for use as a vehicle fuel in California
and Oregon. We sell these credits to third parties who need the RINs and LCFS Credits to comply with federal and state
emissions compliance requirements. Generally, the amount of RINs and LCFS Credits we generate increases as we sell
higher volumes of RNG and conventional natural gas as a vehicle fuel; however, the amount of credits we sell and our
revenue from these sales can vary depending on a number of factors, including the market for these credits, which has
been volatile and subject to significant price fluctuations in recent periods (in 2019 market prices for RINs were as high
as approximately $1.90 and as low as approximately $0.50), any changes to the federal and state programs under which
the credits are generated and sold, and our ability to strictly comply with these programs.
O&M Services. We perform O&M services for fueling stations that we do not own. For these services, we generally
charge a fixed or a per-gallon fee based on the volume of fuel dispensed at the station. We have an operations team that
performs preventive maintenance and is available to respond to service requests.
Station Construction and Engineering. We design and construct fueling stations and facility modifications and sell
or lease some of these stations to our customers. We charge construction or other fees or lease rates based on the size and
complexity of the project. Since 2008, we have served as the general contractor or supervised qualified third-party
contractors to build over 420 natural gas fueling stations. 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; equipment for a LNG station typically consists of storage tanks, pumps and dispensing equipment. Many of
our fueling stations have separate public access areas for retail customers, which generally have the look, feel and
dispensing rates of gasoline and diesel fueling stations. We also offer assessment, design and modification solutions to
provide operators with code-compliant service and maintenance facilities for natural gas vehicle fleets. For example, our
NGV Easy Bay product is a natural gas vapor leak barrier developed specifically for natural gas vehicle facilities.
Vehicle Acquisition and Finance. We offer vehicle finance services, including loans and leases, to help our
customers acquire natural gas vehicles. As appropriate, we apply for and receive federal, state and local incentives
associated with natural gas vehicle purchases and pass these benefits through to our customers. We may also secure
vehicles to place with customers and/or pay deposits with respect to these vehicles before receiving a firm order from our
customers, which we may be required to purchase if our customers fail to purchase the vehicle as anticipated.
Grant Programs. We apply for and help our fleet customers apply for federal, state and local grant programs in
areas in which we operate. These programs can provide funding for natural gas vehicle conversions and purchases, natural
gas fueling station construction and natural gas vehicle fuel sales.
Former Activities. Before March 31, 2017, we produced at our own production plants a portion of the RNG that we
sold. On March 31, 2017 we completed the BP Transaction, in which we sold to BP certain assets related to this RNG
production business, including two RNG production facilities, a 50% ownership interest in joint ventures formed to
develop two new RNG production facilities, and third-party RNG supply contracts.
Before December 29, 2017, we, through our former subsidiary IMW Industries Ltd. (formerly known as Clean Energy
Compression Corp.) (“CEC”), manufactured natural gas fueling compressors and other equipment used in CNG stations.
On December 29, 2017 we completed the CEC Combination, in which we combined CEC with SAFE S.p.A, the natural
gas fueling compressor subsidiary of LR, in a new company, SAFE&CEC S.r.l. SAFE&CEC S.r.l. is focused on
manufacturing, selling and servicing natural gas fueling compressors and related equipment for the global natural gas
fueling market. We and LR own 49% and 51%, respectively, of SAFE&CEC S.r.l.
Customer Markets
We serve customers in a variety of markets, including trucking, airports, refuse, public transit, industrial and
institutional energy users and government fleets. We believe these customer markets are well-suited for the adoption of
natural gas vehicle fuel because they consume relatively high volumes of fuel, refuel at centralized locations or along well-
defined routes and/or are facing increasingly stringent emissions or other environmental requirements. During the years
8
ended December 31, 2017, 2018, and 2019, no single customer accounted for 10% or more of our total revenue. See Note
22 for additional information
Trucking. We believe heavy-duty trucking represents the greatest opportunity for natural gas to be used as a vehicle
fuel in the United States, and as of December 31, 2019, we fuel over 4,000 heavy-duty trucks. Because these high-mileage
vehicles consume substantial amounts of fuel, they can derive significant benefits from the lower cost of natural gas. We
are focused on fueling more natural gas heavy-duty trucks, and many well-known shippers, manufacturers, retailers and
other truck fleet operators have started to adopt natural gas fueled trucks to move their freight. Companies that have
adopted natural gas fueled trucks include Pepsi Frito-Lay, FedEx, Anheuser-Busch, USPS, Bimbo Bakeries, UPS,
MillerCoors, Unilever, Kroger, P&G, KeHe and Owens Corning.
Zero Now. To help facilitate the transition of trucking fleets to natural gas, we have launched the Zero Now truck
financing program, which is intended to increase the deployment of the commercially available ultra-low NOx natural gas
heavy-duty trucks in the United States and encourage these operators to fuel their trucks at our stations. The Zero Now
program generally involves the following:
• One or more truck leasing or finance companies will lease or sell ultra-low NOx natural gas heavy-duty trucks to
vehicle fleets pursuant to lease or sale agreements with the fleet operators and with us, providing for periodic
payments by the fleet operators of amounts equal to the payments that will be made for the lease or purchase of
an equivalent truck that operates on diesel fuel, and providing for payment by us of the incremental cost of the
natural gas truck over and above the diesel-equivalent truck; and
• The fleet operators participating in the program will enter into fueling agreements with us, under which the
operators will agree to purchase from us, and we will agree to supply, minimum monthly volumes of natural gas
fuel at fixed prices (lower than diesel prices) in order to operate the trucks leased or purchased in the program
and allow us to recoup our payment of the incremental cost of the natural gas trucks.
We have entered into the following agreements to implement the Zero Now program:
•
•
•
In January 2019, we entered into a term credit agreement with Société Générale (“SG”), as lender, under which
we are permitted to draw, from time to time, through the beginning of January 2022, up to an aggregate of $100.0
million in order to satisfy our payment obligations for the incremental cost of natural gas trucks under the truck
lease or sale agreements described above;
In January 2019, we entered into a credit support agreement with Total Holdings USA Inc. (“THUSA”), a wholly
owned subsidiary of TOTAL S.A. (“TOTAL”) (which indirectly through another of its subsidiaries, holds
approximately 25% of our outstanding common stock), pursuant to which THUSA has guaranteed our obligations
under the term credit agreement with SG. In consideration for such guaranty, we have agreed to pay to THUSA
a quarterly fee at a rate per annum equal to 10% of the average amount owed by us under the term credit agreement
during the preceding quarter; and
In October 2018, we entered into commodity swap arrangements with Total Gas & Power North America, an
affiliate of TOTAL and THUSA, to manage diesel price fluctuation risks related to the natural gas fuel supply
commitments we expect to make in our anticipated fueling agreements with fleet operators that participate in the
Zero Now program. The swap arrangements cover five million diesel gallons of natural gas fuel volume annually
from April 2019 through June 2024.
For more information about the Zero Now program and the related agreements, see “Item 1A. Risk Factors” and Note
13.
In addition, we are supporting the growth of the natural gas heavy-duty truck market through our negotiation of
favorable CNG and LNG fuel tank pricing from manufacturers, which we are passing along to our customers, and our
network of natural gas truck-friendly fueling stations (we refer to this network as “America’s Natural Gas Highway” or
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“ANGH”), which we have built in key locations nationwide. Many existing ANGH stations are located at Pilot Travel
Centers, the largest truck fueling operator in the United States.
Airports. We estimate that vehicles serving airports in the United States, including airport delivery fleets, rental car
and parking passenger shuttles and taxis, consume an aggregate of approximately two billion gallons of fuel per year.
Additionally, 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. As a result, many of these airports have adopted various
strategies to address tailpipe emissions, including rental car and hotel shuttle consolidation and requiring or encouraging
service vehicle operators to switch their fleets to natural gas. 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 properties.
As of December 31, 2019, we serve customers at 39 airports, including Atlanta Hartsfield Jackson International,
Baltimore Washington International, Dallas-Ft. Worth International, Denver International, Dulles International
(Washington D.C.), George Bush International (Houston), Las Vegas, Logan International (Boston), LaGuardia (New
York City), John F. Kennedy International (New York City), Los Angeles International, Newark International, Oakland
International, Orlando, Phoenix Sky Harbor International, San Francisco International, San Diego International, SeaTac
International (Seattle) and Tampa International.
Refuse. According to INFORM, there are nearly 200,000 refuse trucks in the United States that collect and haul refuse
and recyclables, which collectively consume approximately two billion gallons of fuel per year. We estimate that
approximately 55% of new refuse trucks in 2019 operate on natural gas, up from approximately 3% of new refuse trucks
in 2008. Refuse haulers are increasingly adopting trucks that run on RNG and CNG to realize operational savings and to
address their customers’ demands for reduced emissions.
As of December 31, 2019, we fuel over 13,000 refuse vehicles for customers including Waste Management and
Republic Services, as well as other waste haulers such as Atlas Disposal, Burrtec, Recology, Waste Connections and Waste
Pro, among others. We also provide vehicle fueling services to municipal refuse fleets, including fleets in Dallas, Los
Angeles, San Antonio and New York City, among other locations.
Public Transit. According to the American Public Transportation Association, there are over 66,000 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. Also, transit agencies typically fuel at a central location and use high volumes
of fuel. We estimate that transit agencies in the United States consume approximately 1.0 billion gallons of fuel per year.
Many transit agencies have been early adopters of natural gas vehicles, and over 25% of existing transit buses and over
35% of new transit buses operate on natural gas.
As of December 31, 2019, we fuel over 9,000 transit vehicles for customers including Los Angeles County
Metropolitan Transit Authority, Foothill Transit (Los Angeles County, California), Orange County Transit Authority,
Santa Monica Big Blue Bus, Dallas Area Rapid Transit Phoenix Transit, New Jersey Transit, Jacksonville Transportation
Authority, NICE Bus (Nassau County, New York) and Washington Metro Area Transportation Authority, as well as public
transit customers in British Columbia.
Industrial and Institutional Customers. NG Advantage uses its virtual natural gas pipelines and interconnects to serve
a number of customers that do not have direct access to natural gas pipelines or desire to take advantage of commodity
price differences. We also transport LNG to customers via virtual natural gas pipelines.
Government Fleets. In 2017, 2018 and 2019, contracts with government entities, such as municipal transit fleets,
accounted for approximately 19%, 22% and 21% of our revenue, respectively.
Our representative government fleet customers include the California Department of Transportation, State of New
York, State of Colorado, City of New York, City of Denver, City and County of Los Angeles, City of Newport Beach,
South Coast Air Quality Management District (Southern California region), City and County of San Francisco, City of
Oakland, City and County of Dallas, City of Phoenix, The University of California, and Oklahoma State University.
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Competition
The market for vehicle fuels is highly competitive. We believe the biggest competition for RNG, CNG and LNG use
as a vehicle fuel is gasoline and diesel because the vast majority of vehicles in our key markets are powered by these fuels.
We also compete with suppliers of other alternative vehicle fuels, including renewable diesel, biodiesel and ethanol, as
well as producers and fuelers of alternative vehicles, including hybrid, electric and hydrogen-powered vehicles.
Additionally, our stations compete directly with other natural gas fueling stations and indirectly with electric vehicle
charging stations and fueling stations for other vehicle fuels.
A number of established businesses are in the market for natural gas and other alternatives for use as vehicle fuel,
including alternative vehicle and alternative fuel companies, refuse collectors, industrial gas companies, truck stop and
fuel station owners, fuel providers, utilities and their affiliates and other organizations. If the alternative vehicle fuel market
grows in the future, then the number and type of participants in this market and their level of capital and other commitments
to alternative vehicle fuel programs could increase. We believe there are approximately 20 competitors in the market for
natural gas vehicle fuels in the U.S. and Canada, including:
• Marketers of RNG, including Element Markets, IOGEN, Shell, TruStar, Gain Clean Fuels and Love’s Trillium;
• Providers of CNG fuel infrastructure and fueling services, including Love’s Trillium, Gain Clean Fuels, TruStar
Energy, and American Natural Gas;
• Fuel station owners, such as Kwik Trip, a company that owns CNG fueling stations in the Midwestern United
States;
• Applied LNG Technology and Stabilis Energy, each of which distributes LNG; and
• Utilities and their affiliates in several states, including California, Georgia, Michigan, New Jersey, North
Carolina, Utah and Washington, which own and operate public access CNG stations that compete with our
stations and also compete with us for RNG supply.
We also face high levels of competition with respect to our other business activities. For instance, we compete with
many third parties for the rights to procure RNG from producers and for customers to purchase the RNG that we sell. In
addition, we transport and sell CNG through NG Advantage’s virtual natural gas pipelines and interconnects and compete
with other participants in this market, including Xpress Natural Gas, Certarus, Thigpen, OsComp Systems and Irving Ltd.
We compete for vehicle fuel users based on demand for the type of fuel, which may be affected by a variety of factors,
including, among others, cost, supply, availability, quality, cleanliness and safety of the fuel; cost, availability and
reputation of vehicles and engines; convenience and accessibility of fueling stations; and recognition of the brand. We
believe we compare favorably with our competitors on the basis of these factors; however, some of our competitors have
substantially greater financial, marketing and other resources than we have. As a result, these competitors may be able to
respond more quickly to changes in customer preferences, legal requirements or other industry or regulatory trends; devote
greater resources to the development, promotion and sale of their products; adopt more aggressive pricing policies,
dedicate more effort to infrastructure and systems development in support of their business or product development
activities; implement more robust or creative initiatives to advance consumer acceptance of their products; or exert more
influence on the regulatory landscape that impacts the vehicle fuels market.
We expect competition to increase in the vehicle fuels markets generally. In addition, if the demand for natural gas
vehicle fuel increases, then we expect competition in the market for natural gas vehicle fuel would also increase.
Government Regulation and Environmental Matters
We are subject to a variety of federal, state and local laws and regulations relating to the environment, health and
safety, labor and employment, building codes and construction, zoning and land use, the government procurement process,
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any political activities or lobbying in which we may engage, public reporting and taxation, among others. Many of these
laws and regulations are complex, change frequently and have become more stringent over time. Any changes to existing
regulations, adoption of new regulations or failure by us to comply with applicable regulations may result in significant
additional expense to us or our customers or a variety of administrative, civil and criminal enforcement measures, any of
which could have a material adverse effect on our business, reputation, financial condition and results of operations.
Regulations that significantly affect our various operating activities are described below. Compliance with these
regulations has not had a material effect on our capital expenditures, earnings or competitive position to date, but new
regulations or amendments to existing regulations to make them more stringent could have such an effect in the future.
We cannot estimate the expenses we may incur to comply with potential new laws or changes to existing laws, or the other
potential effects these laws may have on our business, and these unknown costs and effects are not specifically
contemplated by our existing customer agreements or our budgets and cost estimates.
Construction and Operation of CNG and LNG Stations. To construct a CNG or LNG fueling station, we must satisfy
permitting and other requirements and either we or a third-party contractor must be licensed as a general engineering
contractor. Each CNG and LNG fueling station must be constructed in accordance with federal, state and local regulations
pertaining to station design, environmental health, accidental release prevention, above-ground storage tanks and
hazardous waste and other materials. For fueling stations we operate, we are also required to register with certain state
agencies as a retailer/wholesaler of CNG and LNG. We also may benefit from any grant programs or similar government
incentives that may be available for the construction of natural gas fueling stations.
Transfer of LNG. Federal safety standards require each transfer of LNG to be conducted in accordance with specific
written safety procedures. These procedures must require that qualified personnel be in attendance during all LNG transfer
operations, and these procedures must be implemented, and copies of the procedures must be available or displayed, at
each LNG transfer location.
Construction and Operation of LNG Liquefaction Plants. To build and operate LNG liquefaction plants, we must
apply for facility permits or licenses that address many aspects of plant operations, including storm water and wastewater
discharges, waste handling and air emissions related to production activities and equipment operation. The construction of
LNG plants must also be approved by local planning boards and fire departments.
Vehicle Finance. 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 required to be registered as a finance lender
with the California Department of Corporations.
Generation and Sale of RIN Credits and LCFS Credits. In February 2010, the EPA finalized the RFS (which was
established by the Energy Policy Act of 1992/2005), which creates RINs that can be generated by the production and use
of RNG in the transportation sector and sold to fuel providers that are not compliant under the RFS. In addition, CARB
and comparable agencies in Oregon have adopted the Low Carbon Fuel Standard, which encourages low carbon
“compliant” transportation fuels (including CNG, LNG and RNG) in the California and Oregon marketplace by allowing
producers of these fuels to generate LCFS Credits that can be sold to noncompliant regulated parties.
Sale of Natural Gas Vehicle Fuel: AFTC. Under separate pieces of U.S. federal legislation, we have been eligible to
receive the AFTC, an alternative fuels tax credit, for our natural gas vehicle fuel sales made between October 1, 2006 and
December 31, 2019, and are eligible to receive AFTC for our natural gas vehicle fuel sales made during the year ending
December 31, 2020. The AFTC credit is equal to $0.50 per gasoline gallon equivalent of CNG that we sold as vehicle fuel,
and $0.50 per diesel gallon equivalent of LNG that we sold as vehicle fuel in 2017, 2018 and 2019, and sell in 2020. Based
on the service relationship with our customers, either we or our customers claim the credit. On February 9, 2018, AFTC
was retroactively extended from January 1, 2017 to December 31, 2017, and AFTC revenue for the 2017 calendar year
was recognized and collected in 2018. On December 20, 2019, AFTC was retroactively extended beginning January 1,
2018 through December 31, 2020. AFTC revenue for 2018 and 2019 was recognized in 2019. AFTC may not be reinstated
for vehicle fuel sales after December 31, 2020.
Sale of Natural Gas Vehicle Fuel, Operation of Fueling Stations and Production of LNG: Greenhouse Gas Emissions
Regulation. California has enacted laws and regulations that require specified greenhouse gas emissions reductions, and
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the federal government and several other state governments are considering similar measures. These regulations, if and
when adopted and implemented, could affect several areas of our operations, including our sales of conventional and
renewable natural gas and the operation of our CNG and LNG fueling stations and our LNG production plants.
California’s emissions laws require statewide reductions of greenhouse gas emissions to 1990 levels by 2020, 40%
below 1990 levels by 2030, and 80% below 1990 levels by 2050. As of January 1, 2015, California’s AB 32 law began
regulating the greenhouse gas emissions from transportation fuels, including the emissions associated with the CNG and
LNG vehicle fuel we sell in the state.
Under AB 32, the regulated party with respect to CNG vehicle fuel use is the utility that owns the pipe through which
the fossil fuel natural gas is sold. We anticipate that, over time, as the utilities’ costs increase to comply with this law, we
or, to the extent we pass these costs through to our customers, our CNG customers will be required to pay more for CNG
vehicle fuel to cover the increased AB 32 compliance costs of the utility. The amount of these costs that we or our CNG
customers will be required to pay will be determined by the amount a utility spends to buy any carbon credits needed to
comply with AB 32 and the amount of natural gas we or our customers buy through the utility’s pipeline. With respect to
LNG vehicle fuel use, the LNG vehicle fuel provider is the regulated party under AB 32. As a result, we will incur
increased costs to comply with AB 32, and the amount of the increase will be based on how much LNG vehicle fuel we
sell that is regulated, CARB’s requirements relating to the regulation of LNG vehicle fuel, any applicable regulatory
changes and the cost of any carbon credits we purchase to comply with AB 32. We expect to try to pass the costs we incur
to comply with this law through to our LNG customers. To the extent we are not able to pass the increased costs of CNG
and LNG vehicle fuel as a result of AB 32 through to our customers, we could experience increased direct expenses and
reduced margins.
Sales and Marketing
We market our brands, products and services primarily through our direct sales force, which includes sales
representatives covering all of our major geographic and customer markets, as well as attendance at trade shows and
participation in industry conferences and events. Our sales and marketing team also works closely with federal, state and
local government agencies to provide education about the value of natural gas as a vehicle fuel and to keep abreast of
proposed and newly adopted regulations that affect our industry.
Employees
As of December 31, 2019, we employed 412 people. We have not experienced any work stoppages and none of our
employees is subject to collective bargaining agreements. We believe our employee relations are good.
Seasonality
To some extent, our business may experience seasonality. For more information, see the discussion under “Seasonality
and Inflation” in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Intellectual Property
Our intellectual property rights primarily consist of trade secrets, know-how and trademarks, and we rely on a
combination of trademark laws, trade secret laws, confidentiality provisions and other contractual provisions to protect
these rights and our proprietary information. These intellectual property rights help us to retain existing business and secure
new relationships with customers.
Corporate Information
We were incorporated under the laws of the State of Delaware in 2001. We have completed, and we anticipate
continuing to pursue, acquisitions, investments, divestitures, joint ventures and other partnerships as we become aware of
opportunities that we believe can increase our competitive advantages, expand our product offerings, take advantage of
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industry developments and trends, enhance our market position or provide other benefits, including streamlining operations
and reducing our costs. Recent significant transactions of this nature include the BP Transaction and the CEC Combination.
More Information
Our website is located at www.cleanenergyfuels.com. We make available, free of charge on our website, our annual
reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports filed
or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act as soon as reasonably practicable after we
electronically file such material with, or furnish it to, the SEC. The SEC maintains a website at www.sec.gov that contains
reports, proxy and information statements and other information regarding issuers that file electronically with the SEC,
including us.
All references to our website in this report are inactive textual references and the contents of our website are not
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 report before you make any investment decision regarding
our securities. We believe the risks and uncertainties described below are the most significant we face, but additional risks
and uncertainties not known to us or that we currently deem immaterial could also be or become significant. The
occurrence of any of these risks could harm our business, financial condition, results of operations, prospects and
reputation and could cause the trading price of our common stock to decline.
Risks Related to Our Business
Our success is dependent on the willingness of fleets and other consumers to adopt natural gas as a vehicle fuel, which
may not occur in a timely manner, at expected levels or at all.
Our success is highly dependent on the adoption by fleets and other consumers of natural gas as a vehicle fuel. The
market for natural gas as a vehicle fuel has experienced slow, volatile and unpredictable growth in many sectors. For
example, adoption and deployment of natural gas vehicles, both in general and in certain of our key customer markets,
including heavy-duty trucking, have been slower and more limited than we anticipated. Also, other important fleet markets,
including airports, refuse and public transit, had slower volume and customer growth in 2018 and 2019 that may continue.
Moreover, adoption of and demand for the different types of natural gas vehicle fuel, including CNG, LNG and RNG
(which can be delivered in the form of CNG or LNG), are subject to significant risks, including decreased LNG volumes
in some markets in recent periods that may continue and may not be sufficiently offset by any increase in demand for RNG
or CNG. If the market for natural gas as a vehicle fuel does not develop at improved rates or levels, or if a market develops
but we are not able to capture a significant share of the market or the market subsequently declines, our business, prospects,
financial condition and operating results would be harmed.
Factors that may influence the adoption of natural gas as a vehicle fuel, many of which are beyond our control, include,
among others:
• Adoption of government policies or programs or increased publicity or popular sentiment in favor of vehicles or
vehicle fuels other than natural gas, including long-standing support for gasoline and diesel-powered vehicles and
growing support for electric and hydrogen-powered vehicles;
• Perceptions about the benefits of renewable and conventional natural gas relative to gasoline and diesel and other
alternative vehicle fuels, including with respect to factors such as supply, cost savings, environmental benefits
and safety;
•
Increases, decreases or volatility in the supply, demand, use and prices of crude oil, gasoline, diesel, natural gas
and other vehicle fuels, such as electricity, hydrogen, renewable diesel, biodiesel and ethanol;
14
•
Inertia among fleets and fleet vehicle operators, who may be unable or unwilling to prioritize converting a vehicle
fleet to natural gas over an operator’s other general business concerns, particularly if the operator lacks sufficient
incentive to convert from emissions regulations or other requirements or lacks demand for the conversion from
its customers or drivers;
• Natural gas vehicle cost, fuel usage, availability, quality, safety, convenience (to fuel and service), design,
performance and residual value, as well as operator perception with respect to these factors, generally and in our
key customer markets and relative to comparable vehicles powered by other fuels;
• The development, production, cost, availability, performance, sales and marketing and reputation of natural gas
engines that are well-suited for the vehicles used in our key customer markets, including heavy-duty trucks and
other fleets;
•
Increasing competition in the market for vehicle fuels generally, and the nature and effect of competitive
developments in this market, including improvements in or perceived advantages of non-natural gas vehicle fuels
or engines powered by these fuels;
• The availability and effect of environmental, tax or other government regulations, programs or incentives that
promote natural gas or other alternatives as a vehicle fuel, including certain programs under which we generate
credits by selling conventional and renewable natural gas as a vehicle fuel, as well as the market prices for such
credits;
• The effect of, or potential for changes to, emissions requirements applicable to vehicles powered by gasoline,
diesel, natural gas or other vehicle fuels;
• Emissions and other environmental regulations and pressures on crude oil and natural gas fueling stations and
drilling, production, importing and transportation methods for these fuels; and
• The other risks discussed in these risk factors.
We are dependent on the production of natural gas vehicles and engines in our key customer and geographic markets
by vehicle and engine manufacturers, over which we have no control.
Natural gas vehicle and engine manufacturers control the development, production, quality assurance, cost and sales
and marketing of their products, which shapes the performance, availability and reputation of these products in the
marketplace. Although we are dependent on these manufacturers to succeed in our target markets, we have no influence
over their activities. For example, Cummins Westport is the only natural gas engine manufacturer for the heavy-duty truck
market in the United States, and this and other original equipment manufacturers currently produce a relatively small
number of natural gas engines and vehicles for the U.S. and Canadian markets. These manufacturers may not decide to
expand or maintain, or may decide to discontinue or curtail, their natural gas engine or vehicle product lines. The limited
production of natural gas engines and vehicles increases their cost and limits availability, which restricts large-scale
adoption, and may reduce resale value, which may contribute to operator reluctance to convert their vehicles to natural
gas. In addition, some operators have communicated to us that the first generation models of natural gas engines for heavy-
duty trucks have a reputation for unsatisfactory performance, and that this reputation or their first-hand experiences of
such performance may be a factor in operator decisions regarding whether or not to convert their fleets to natural gas. The
success of our business strategies and initiatives depends on sufficient availability and adoption of high-performing natural
gas vehicles, and as a result, any production failures by the third-party manufacturers of these vehicles or their engines
could harm our results of operations, business and prospects.
If there are improvements in or perceived advantages of non-natural gas vehicle fuels or engines powered by these
fuels, demand for natural gas vehicles may decline.
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Use of electric heavy-duty trucks, buses and refuse trucks, which are key customer markets for our business, or the
perception that electric vehicles providing satisfactory performance at an acceptable cost may soon be widely available
for these or other applications, could reduce demand for natural gas vehicles generally and in these key markets. In
addition, hydrogen, renewable diesel and other alternative fuels in development may prove to be, or may be perceived to
be, cleaner, more cost-effective, more readily available or otherwise more beneficial alternatives to gasoline and diesel
than conventional or renewable natural gas. Further, technological advances in the production, delivery and use of gasoline,
diesel or other alternative vehicle fuels, or the failure of natural gas vehicle fuel technology to advance at an equal pace,
could slow or limit adoption of natural gas vehicles. For example, advances in gasoline and diesel engine technology,
including efficiency improvements and further development of hybrid engines, may offer a more cost-effective way for
operators to use a cleaner vehicle fuel, which could reduce the likelihood that fleet customers purchase natural gas vehicles
or convert their existing vehicles to natural gas. If any of these risks occur, our industry, prospects and results could
materially suffer.
We have a history of losses and may incur additional losses in the future.
We incurred pre-tax losses in 2017 and 2018. During 2018 and 2019, our results were positively affected by $26.7
million and $47.1 million of AFTC revenue, respectively. We may incur losses in future periods and we may never sustain
profitability, either of which would adversely affect our business, prospects and financial condition and may cause the
price of our common stock to fall. In addition, to try to achieve or sustain profitability, we may choose or be forced to take
actions that result in material costs or material asset or goodwill impairments. For instance, in the third and fourth quarters
of 2017, we recorded significant charges in connection with our former natural gas fueling compressor manufacturing
business (which we subsequently combined with another company’s natural gas fueling compressor manufacturing
business in the CEC Combination), our closure of certain fueling stations, our determination that certain assets were
impaired as a result of the foregoing, and other actions. We review our assets for impairment whenever events or changes
in circumstances indicate that the carrying value of an asset or asset group may not be recoverable and we perform a
goodwill impairment test on an annual basis and between annual tests in certain circumstances, in each case in accordance
with applicable accounting guidance and as described in the financial statements and related notes included in this report.
Changes to the use of our assets, divestitures, changes to the structure of our business, significant negative industry or
economic trends, disruptions to our operations, inability to effectively integrate any acquired businesses, further market
capitalization declines, or other similar actions or conditions could result in additional asset impairment or goodwill
impairment charges or other adverse consequences, any of which could have material negative effects on our financial
condition, our results of operations and the trading price of our common stock.
Our business is influenced by environmental, tax and other government regulations, programs and incentives that
promote natural gas or other alternatives as a vehicle fuel, and their adoption, modification or repeal could negatively
affect our business.
Our business is influenced by federal, state and local tax credits, rebates, grants and other government programs and
incentives that promote the use of RNG, CNG and LNG as a vehicle fuel. These include various government programs
that make grant funds available for the purchase of natural gas vehicles and construction of natural gas fueling stations, as
well as the AFTC tax credit under which we generate revenue for our natural gas vehicle fuel sales made through the end
of 2020 but which may not be available for vehicle fuel sales made after December 31, 2020, particularly if other legislative
priorities result in insufficient focus on this program during upcoming congressional sessions. Additionally, our business
is influenced by laws, rules and regulations that require reductions in carbon emissions and/or the use of renewable fuels,
such as the programs under which we generate RINs and LCFS Credits by selling RNG, CNG and LNG as a vehicle fuel.
These programs and regulations, which have the effect of encouraging the use of RNG, CNG or LNG as a vehicle
fuel, could expire or be repealed or amended for a variety of reasons. For example, parties with an interest in gasoline and
diesel, electric or other alternative vehicles or vehicle fuels, including lawmakers, regulators, policymakers, environmental
or advocacy organizations or other powerful groups, may invest significant time and money in efforts to delay, repeal or
otherwise negatively influence regulations and programs that promote natural gas. Many of these parties have substantially
greater resources and influence than we have. Further, changes in federal, state or local political, social or economic
conditions, including a lack of legislative focus on these programs and regulations, could result in their modification,
delayed adoption or repeal. Any failure to adopt, delay in implementing, expiration, repeal or modification of these
16
programs and regulations, or the adoption of any programs or regulations that encourage the use of other alternative fuels
or alternative vehicles over natural gas, would reduce the market for natural gas as a vehicle fuel and harm our operating
results, liquidity and financial condition. For instance, California lawmakers and regulators have implemented various
measures designed to increase the use of electric, hydrogen and other zero-emission vehicles, including establishing firm
goals for the number of these vehicles operating on state roads by specified dates and enacting various laws and other
programs in support of these goals. Although the influence of these or similar measures on our business and natural gas
vehicle adoption in general remains uncertain, a focus by these groups on zero-emission vehicles over vehicles operating
on natural gas adversely affects the market for natural gas vehicles and our business prospects.
Our RNG business may not be successful.
Our RNG business consists of purchasing RNG from third-party producers, including BP, and reselling this RNG
through our natural gas fueling infrastructure as Redeem, our RNG vehicle fuel.
The success of our RNG business depends on our ability to secure, on acceptable terms, a sufficient supply of RNG
from BP and other third parties; to sell this RNG in adequate volumes and at prices that are attractive to customers and
produce acceptable margins for us; and to sell, at favorable prices, credits we may generate under applicable federal or
state programs from our sale of RNG as a vehicle fuel, including RINs and LCFS Credits. If we are not successful at one
or more of these activities, our RNG business could fail and our performance and financial condition could be materially
harmed.
Our ability to maintain an adequate supply of RNG is subject to risks affecting RNG production. Projects that produce
pipeline-quality RNG often experience unpredictable production levels or other difficulties due to a variety of factors,
including, among others, problems with equipment, severe weather, construction delays, technical difficulties, high
operating costs, limited availability or unfavorable composition of collected feedstock gas, and plant shutdowns caused by
upgrades, expansion or required maintenance. In addition, increasing demand for RNG will result in more robust
competition for supplies of RNG, including from other vehicle fuel providers, gas utilities (which may have distinct
advantages in accessing RNG supply including potential use of ratepayer funds to fund RNG purchases if approved by a
utility’s regulatory commission) and other users and providers. If any of our RNG suppliers experience these or other
difficulties in their RNG production processes, or if competition for RNG supply materially increases, then our supply of
RNG and our ability to resell it as a vehicle fuel could be jeopardized.
Our ability to generate revenue from our sale of RNG or our generation and sale of RINs and LCFS Credits depends
on a number of factors, including the markets for RNG as a vehicle fuel and for these credits. The market for RNG as a
vehicle fuel is subject to the same fluctuations and unpredictability that affect the market for natural gas vehicle fuel
generally, which is discussed elsewhere in these risk factors. The markets for RINs and LCFS Credits have been volatile
and unpredictable in recent periods, and the prices for these credits have been subject to fluctuations, including lower
market prices for RINs since June 2019 that may continue. For example, in 2019 market prices for RINs were as high as
approximately $1.90 and as low as approximately $0.50. Additionally, the value of RINs and LCFS Credits, and
consequently the revenue levels we may receive from our sale of these credits, may be adversely affected by changes to
the federal and state programs under which these credits are generated and sold or other market conditions. Further, our
ability to generate revenue from sales of these credits depends on our strict compliance with these federal and state
programs, which are complex and can involve a significant degree of judgment. If the agencies that administer and enforce
these programs disagree with our judgments, otherwise determine we are not in compliance, conduct reviews of our
activities or make changes to the programs, then our ability to generate or sell these credits could be temporarily restricted
pending completion of reviews or as a penalty, permanently limited or lost entirely, and we could also be subject to fines
or other sanctions. Any of these outcomes could force us to purchase credits in the open market to cover any credits we
have contracted to sell, retire credits we may have generated but not yet sold, reduce or eliminate a significant revenue
stream or incur substantial additional and unplanned expenses. We experienced many of these effects in connection with
the administrative review by the CARB of our generation of LCFS Credits in the third and fourth quarters of 2017, during
which we were restricted from selling and transferring accumulated LCFS Credits, we were required to make cash
payments to third parties to settle preexisting commitments to transfer LCFS Credits, and certain of our LCFS Credits
were invalidated. See the discussion under “Key Trends—Our Performance” in the MD&A in this report for more
information about this administrative review and its effects. Moreover, in the absence of programs that allow us to generate
17
and sell RINs and LCFS Credits or other federal and state programs that support the RNG vehicle fuel market, or if our
customers are not willing to pay a premium for RNG, we may be unable to operate our RNG business profitably or at all.
Any such failure of our RNG business could have a significant negative effect on our performance, cash position and
prospects.
Increases, decreases and general volatility in oil, gasoline, diesel and natural gas prices could adversely affect our
business.
Gasoline and diesel are today's most prevalent vehicle fuels. Prices for crude oil, which is the commodity used to
make gasoline and diesel, have been low in recent years, due in part to over-production and increased supply without a
corresponding increase in demand. If the prices of crude oil, gasoline and diesel continue to be low or decline further, or
if the price of natural gas increases without corresponding increases in the prices of crude oil, gasoline and diesel, then
market adoption of natural gas as a vehicle fuel could be slowed or limited. Further, any of these circumstances could
decrease the market's perception of a need for alternative vehicle fuels generally, which could cause the prospects for and
success of our industry and our business to materially suffer. In addition, under these pricing conditions, we may not be
able to offer our customers an attractive price advantage for RNG, CNG and LNG and maintain an acceptable margin on
our sales. Any such failure could result in an inability to attract new customers or a loss of demand from existing customers,
or could directly and negatively affect our results of operations if we are forced to reduce the prices at which we sell natural
gas to try to avoid such an effect. Conversely, if prices of gasoline and diesel increase or the price of natural gas decreases,
we may not be able to capture a material portion of any increase in the demand for natural gas vehicle fuel that could result
from favorable pricing conditions, due to increased competition from new entrants in the natural gas vehicle fuels market,
expanded programs by existing competitors, or other factors.
Pricing conditions may also exacerbate the cost differential between natural gas vehicles and gasoline or diesel-
powered vehicles, which may lead operators to delay or refrain from purchasing or converting to natural gas vehicles.
Generally, natural gas vehicles cost more initially than gasoline or diesel-powered vehicles because the components needed
for a vehicle to use natural gas add to the vehicle’s base cost. Operators then seek to recover the additional base cost over
time through the lower cost to fuel a natural gas vehicle. Operators may, however, perceive an inability to timely recover
these additional initial costs if RNG, CNG and LNG fuel are not available at prices sufficiently lower than gasoline and
diesel. Such an outcome could decrease our potential customer base and harm our business prospects.
Additionally, the prices of natural gas, crude oil, gasoline and diesel have been volatile in recent years, and this
volatility may continue. Factors that may cause this volatility to continue include, among others, changes in supply and
availability of crude oil and natural gas, government regulations, inventory levels, consumer demand, price and availability
of alternatives, weather conditions, negative publicity about crude oil or natural gas drilling, production or importing
techniques and methods, economic, health and political conditions, transportation costs and the price of foreign imports.
Fluctuations in natural gas prices affect the cost to us of the natural gas commodity. High natural gas prices adversely
affect our operating margins when we cannot pass the increased costs through to our customers. Conversely, lower natural
gas prices reduce our revenue when the commodity cost is passed through to our customers. As a result, continued
fluctuations in natural gas prices could have a significant effect on our operating results.
We face increasing competition from a variety of businesses, many of which have far greater resources, experience,
customer bases and brand awareness than we have, and we may not be able to compete effectively with these businesses.
The market for vehicle fuels is highly competitive. The biggest competition for RNG, CNG and LNG use as a vehicle
fuel is gasoline and diesel because the vast majority of vehicles in our key markets are powered by these fuels. We also
compete with suppliers of other alternative vehicle fuels, including renewable diesel, biodiesel and ethanol, as well as
producers and fuelers of alternative vehicles, including hybrid, electric and hydrogen-powered vehicles. Additionally, our
stations compete directly with other natural gas fueling stations and indirectly with electric vehicle charging stations and
fueling stations for other vehicle fuels. We also face high levels of competition with respect to our other business activities,
including our procurement and sale of RNG and our transport and sale of CNG through the virtual natural gas pipelines
and interconnects of our subsidiary, NG Advantage.
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A number of businesses are in the market for natural gas and other alternatives for use as vehicle fuel, including
alternative vehicle and alternative fuel companies, refuse collectors, industrial gas companies, truck stop and fuel station
owners, fuel providers, gas marketers, utilities and their affiliates and other organizations. If the alternative vehicle fuel
market grows, then the number and type of participants in this market and their level of capital and other commitments to
alternative vehicle fuel programs could increase. Many of our competitors have substantially greater experience, customer
bases, brand awareness and financial, marketing and other resources than we have. As a result, these competitors may be
able to respond more quickly to changes in customer preferences, legal requirements or other industry or regulatory trends;
devote greater resources to the development, promotion and sale of their products; adopt more aggressive pricing policies;
dedicate more effort to infrastructure and systems development in support of their business or product development
activities; implement more robust or creative initiatives to advance consumer acceptance of their products; or exert more
influence on the regulatory landscape that affects the vehicle fuels market.
We expect competition to increase in the vehicle fuels market generally. In addition, if the demand for natural gas
vehicle fuel increases, then we expect competition in the market for natural gas vehicle fuel would also increase. Any such
increased competition may reduce our customer base and revenue and may lead to increased pricing pressure, reduced
operating margins and fewer expansion opportunities.
Our Zero Now heavy-duty truck financing initiative subjects us to material risks, and if this program is not successful,
our financial results and business could be materially adversely affected.
One of our key strategic objectives is to fuel more natural gas heavy-duty trucks. As part of our efforts to achieve this
goal, we have launched the Zero Now truck financing program, which is intended to facilitate and increase the deployment
of natural gas heavy-duty trucks in the United States and encourage these operators to fuel their trucks at our stations. The
Zero Now program is unique and complex and subjects us to a variety of risks. See the discussion under “Customer
Markets-Trucking” in Part I, Item 1. Business of this report and Note 13 for information about the structure of the program
and certain agreements we have established in connection with its launch.
The Zero Now program may not be successful for a variety of reasons, including continued slow or limited adoption
of natural gas trucks by fleet operators or the occurrence of any of the other risks described in these risk factors. For
example, some operators have communicated to us that their reluctance to convert to natural gas trucks stems from
insufficient incentive to convert due to emissions regulations or other requirements, lack of demand for the conversion
from customers and drivers, experiences or reputation of unsatisfactory performance by the first generation models of
heavy-duty truck engines, actual or perceived insufficiencies in the financial incentives to convert, concern regarding the
residual value of heavy-duty trucks and prioritization of other competing business concerns. If a sufficient number of truck
operators do not participate in the Zero Now program, then it will not achieve its intended benefits and we will have
expended substantial resources on an initiative that does not produce results.
In addition, the structure and terms of the program subject us to certain additional risks. For example, the term credit
agreement we have established to implement the program permits us to incur substantial additional debt, and the related
credit support agreement obligates us to make quarterly payments in amounts that will vary depending on the outstanding
principal under the term credit agreement. These commitments are subject to, and will amplify, the risks associated with
our outstanding indebtedness, which are discussed elsewhere in these risk factors. In addition, the amounts owed under
the term credit agreement and the credit support agreement use LIBOR as a benchmark for establishing the rate at which
interest accrues. In July 2017, the U.K.’s Financial Conduct Authority, which regulates LIBOR, announced that it intends
to phase out LIBOR by the end of 2021. We intend to monitor the developments with respect to the potential
discontinuance of LIBOR after 2021 and work with SG, our lender under the term credit agreement, in order to minimize
the effect of such a discontinuance on our financial condition and results of operations; however, the actual effect of the
anticipated discontinuance of LIBOR on us and the cost of this indebtedness remains uncertain. If SG has increased costs
due to changes in LIBOR, we may experience potential increases in interest rates under the term credit agreement, which
could adversely impact our interest expense, results of operations and cash flows. Further, the commodity swap
arrangements we established with an affiliate of TOTAL and THUSA in connection with launching the program introduce
additional risks related to volatility in crude oil prices. These arrangements are designed to protect us from fluctuations in
the price of crude oil; however, we may be subject to payment obligations if truck operators participating in the program
do not use all of the fuel volume covered by the arrangements and we are not able to fully and timely sell the excess fuel
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volume to our other customers. Any obligation to make payments under our commodity swap arrangements would increase
our operating expenses and decrease our available cash flow, and any efforts to sell additional gallons to our other
customers to avoid such payment obligations could result in lower margins and revenues.
Moreover, even if the Zero Now program achieves its intended goal of facilitating growth in the U.S. heavy-duty truck
market, such growth may not positively affect our results for a variety of reasons. For example, if trucks purchased or
financed in the program do not meet the minimum fuel purchase obligations under the supply agreements with us for any
reason, including an operator experiencing lower-than-anticipated fuel demand or failing to comply with payment
obligations under the supply agreement, then the program would not result in the intended growth in our fuel sales volume
and consequent increase in our revenues. Although we have built America’s Natural Gas Highway, or ANGH, our
nationwide network of natural gas truck-friendly fueling stations, some operators may choose to fuel their natural gas
vehicles elsewhere due to lack of convenient access, fuel prices or other factors. In that event, we would remain obligated
to make payments under the debt agreements we have established in connection with the Zero Now program, which are
based on the cost of the trucks purchased or financed in the program and not the amount of fuel volume we actually sell.
As a result, we could become subject to significant payments under these debt agreements without a corresponding increase
in revenues, in which case our performance and liquidity would be materially adversely affected.
We must effectively manage these risks to obtain the anticipated benefits from our Zero Now truck financing program
and achieve our objective of fueling additional natural gas heavy-duty trucks. If we are not successful in meeting these
objectives, our business, financial condition and operating results would be materially and adversely affected.
We may need to raise additional capital to continue to fund our business or repay our debt, which could have negative
effects and may not be available when needed, on acceptable terms or at all.
We require capital to make principal and interest payments on our indebtedness, and to pay for capital expenditures
(including NG Advantage's capital expenditures), our other operating expenses, and any mergers, acquisitions or strategic
investments, transactions or relationships we may pursue. If we cannot fund any of these activities with capital on-hand or
cash provided by our operations, we may seek to obtain additional capital from other sources, such as by selling assets or
pursuing debt or equity financing.
Asset sales and equity or debt financing may not be available when needed, on terms favorable to us or at all. Any
sale of our assets to generate cash proceeds may limit our operational capacity and could limit or eliminate any revenue
streams or business plans that are dependent on the sold assets. Any issuances of our common stock or securities
convertible into our common stock to raise capital would dilute the ownership interest of our existing stockholders. Any
debt financing we may pursue could require us to make significant interest or other payments and to pledge some or all of
our assets as security. In addition, higher levels of indebtedness could increase our risk of non-repayment, adversely affect
our creditworthiness and amplify the other risks associated with our existing debt, which are discussed elsewhere in these
risk factors. Further, we may incur substantial costs in pursuing any capital-raising transactions, including investment
banking, legal and accounting fees. On the other hand, if we are unable to obtain capital in amounts sufficient to fund our
obligations, expenses and strategic initiatives, we could be forced to suspend, delay or curtail our business plans or
operating activities or could default on our contractual commitments. Any such outcome could negatively affect our
business, performance, liquidity and prospects.
Compliance with greenhouse gas emissions regulations may prove costly and negatively affect our performance and
financial condition.
California has enacted laws and regulations that require specified greenhouse gas emissions reductions, and the federal
government and several other state governments are considering similar measures. These regulations could affect several
areas of our operations, including our sales of conventional and renewable natural gas and the operation of our CNG and
LNG fueling stations and our LNG production plants. For instance, California’s AB 32 law, which regulates greenhouse
gas emissions from transportation fuels, including emissions associated with the CNG and LNG vehicle fuel we sell,
imposes increased compliance costs on utilities, suppliers and/or users of CNG and LNG fuel. See the discussion under
“Government Regulation and Environmental Matters - Sale of Natural Gas Vehicle Fuel, Operation of Fueling Stations
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and Production of LNG: Greenhouse Gas Emissions Regulation” in Part I, Item 1. Business of this report for information
about the implementation of AB 32.
The increased costs of CNG and LNG vehicle fuel as a result of AB 32 could diminish the attractiveness of these fuels
for existing and prospective customers in California, which could reduce our customer base and fuel sales in one of our
key geographic markets. Additionally, to the extent we are not able to pass these increased costs through to our customers,
we could experience increased expenses and reduced margins. Any of these outcomes could cause our performance to
suffer, impair our ability to fulfill customer contracts and reduce our cash available for other aspects of our business.
Moreover, if similar laws or regulations are adopted and implemented by other states or by the federal government, or if
existing laws are amended to make them more stringent, any compliance costs associated with the new or amended laws
could amplify these effects. Further, any such new or more stringent laws or regulations could require us to undertake or
incur significant additional capital expenditures or other costs to, among other things, buy emissions or other
environmental credits or invest in costly new emissions prevention technologies. We cannot estimate the expenses we may
incur to comply with potential new laws or changes to existing laws, or the other potential effects these laws may have on
our business, and these unknown costs and effects are not contemplated by our existing customer agreements or our
budgets and cost estimates.
In addition, any failure by us to comply with existing or any future emissions laws or regulations could result in
monetary penalties or a variety of other administrative, civil and criminal enforcement measures, any of which could have
a material adverse effect on our business, reputation, financial condition, liquidity and results of operations.
NG Advantage may not be successful.
NG Advantage’s business consists of transporting and selling CNG for non-vehicle purposes via virtual natural gas
pipelines and interconnects. NG Advantage transports CNG to industrial and institutional energy users that do not have
direct access to natural gas pipelines. NG Advantage also transports CNG between pipelines for customers that desire to
take advantage of commodity price differences. NG Advantage faces unique risks, including among others:
•
It has a history of net losses and has incurred substantial indebtedness;
• NG Advantage will need to raise additional capital, which may not be available, may only be available on onerous
terms, or may only be available from the Company. Recently, we have been the sole source of financing for NG
Advantage, consisting of loans of $26.7 million in the year ended December 31, 2019 and a $5.0 million equity
purchase in the year ended December 31, 2018. If NG Advantage is not able to obtain financing from external
sources, we may need to provide additional debt or equity capital to allow NG Advantage to satisfy its
commitments and maintain operations;
•
It has considerable obligations under its arrangements with BP and other customers, and if NG Advantage fails
to perform under such arrangements it would be subject to significant liquidated damages and we could be subject
to significant cash liabilities pursuant to the terms of our guaranty agreement with NG Advantage and BP (see
the disclosure under “Off-Balance Sheet Arrangements” in the MD&A in this report for more information about
this guaranty agreement);
• The labor market for truck drivers is very competitive, which increases NG Advantage's difficulty in meeting its
delivery obligations;
• NG Advantage transports CNG in trailers over long distances and these trailers may be involved in accidents;
• NG Advantage has been targeted by environmental groups that may disrupt its activities; and
• Many of the other risks discussed in these risk factors.
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If NG Advantage fails to manage any of these risks, our business, financial condition, liquidity results of operations,
prospects and reputation may be harmed.
Our station construction activities subject us to a number of business and operational risks.
As part of our business activities, we design and construct natural gas fueling stations that we either own and operate
ourselves or sell to our customers. These activities require a significant amount of judgment in determining where to build
and open fueling stations, including predictions about fuel demand that may not be accurate for any of the locations we
target. As a result, we have built stations that we may not open for fueling operations and we may open stations that fail
to generate the volume or profitability levels we anticipate, either or both of which could occur due to a lack of sufficient
customer demand at the station locations or for other reasons. For any stations that are completed but unopened, we would
have substantial investments in assets that do not produce revenue, and for any stations that are open and underperforming,
we may decide to close the stations. We determined to close a number of underperforming stations in the third and fourth
quarters of 2017 and recorded impairment charges in connection with these closures and other related actions, and any
further station closures could result in substantial additional costs and non-cash asset impairments or other charges and
could harm our reputation and reduce our potential customer base.
We also face a number of operational challenges in connection with our station design and construction activities. For
example, we may not be able to identify suitable locations for the stations we or our customers seek to build. Additionally,
even if preferred sites can be located, we may encounter land use or zoning difficulties, challenges obtaining and retaining
required permits and approvals or local resistance, any of which could prevent us or our customers from building new
stations on these sites or limit or restrict the use of new or existing stations. Any such difficulties, resistance or limitations
or any failure to comply with local permit, land use or zoning requirements could restrict our activities or expose us to
fines, reputational damage or other liabilities, which would harm our business and results of operations. In addition, we
act as the general contractor and construction manager for new station construction and facility modification projects, and
we typically rely on licensed subcontractors to perform the construction work. We may be liable for any damage we or
our subcontractors cause or for injuries suffered by our employees or our subcontractors’ employees during the course of
work on our projects. Additionally, shortages of skilled subcontractor labor could significantly delay a project or otherwise
increase our costs. Further, our expected profit from a project is based in part on assumptions about the cost of the project,
and cost overruns, delays or other execution issues may, in the case of projects we complete and sell to customers, result
in our failure to achieve our expected margins or cover our costs, and in the case of projects we build and own, result in
our failure to achieve an acceptable rate of return. If any of these events occur, our business, operating results and liquidity
could be negatively affected.
We have significant contracts with government entities, which are subject to unique risks.
We have, and expect to continue to seek, long-term RNG, CNG and LNG station construction, maintenance and fuel
sale contracts with various government bodies, which accounted for 19%, 22% and 21% of our revenue in 2017, 2018,
and 2019, respectively. In addition to normal business risks, including the other risks discussed in these risk factors, our
contracts with government entities are often subject to unique risks, some of which are beyond our control. For example,
long-term government contracts and related orders are subject to cancellation if adequate appropriations for subsequent
performance periods are not made. Further, the termination of funding for a government program supporting any of our
government contracts could result in the loss of anticipated future revenue attributable to the contract. Moreover,
government entities with which we contract are often able to modify, curtail or terminate contracts with us at their
convenience and without prior notice, and would only be required to pay for work completed and commitments made at
or prior to the time of termination.
In addition, government contracts are frequently awarded only after competitive bidding processes, which are often
protracted. In many cases, unsuccessful bidders for government contracts are provided the opportunity to formally protest
the contract awards through various agencies or other administrative and judicial channels. The protest process may
substantially delay a successful bidder’s contract performance, result in cancellation of the contract award entirely and
distract management. As a result, we may not be awarded contracts for which we bid, and substantial delays or cancellation
of contracts may follow any successful bids as a result of any protests by other bidders. The occurrence of any of these
risks would have a material adverse effect on our results of operations and financial condition.
22
Our operations entail inherent safety and environmental risks, which may result in substantial liability to us.
Our operations entail inherent safety risks, including risks associated with equipment defects, malfunctions, failures
and misuses. For example, operation of LNG pumps requires special training because of the extremely low temperatures
of LNG. Also, LNG tanker trailers and CNG fuel tanks and trailers could rupture if involved in accidents or improper
maintenance or installation. Further, improper refueling of natural gas vehicles or operation of natural gas vehicle fueling
stations could result in sudden releases of pressure that could cause explosions. In addition, our stations may vent methane,
a potent greenhouse gas. These safety and environmental risks could result in uncontrollable flows of natural gas, fires,
explosions, death or serious injury, any of which may expose us to liability for personal injury, wrongful death, property
damage, pollution and other environmental damage. We may incur substantial liability and costs if any such damages are
not covered by insurance or are in excess of policy limits, or if environmental damage causes us to violate applicable
greenhouse gas emissions or other environmental laws. Additionally, the occurrence of any of these events with respect to
our fueling stations or our other operations could materially harm our business and reputation. Moreover, the occurrence
of any of these events to any other organization in the natural gas vehicle fuel business could harm our industry generally
by negatively affecting perceptions about, and adoption levels of, natural gas as a vehicle fuel.
Our business is subject to a variety of government regulations, which may restrict our operations and result in costs
and penalties.
We are subject to a variety of federal, state and local laws and regulations relating to the environment, health and
safety, labor and employment, building codes and construction, zoning and land use, the government procurement process,
any political activities or lobbying in which we may engage, public reporting and taxation, among others. It is difficult and
costly to manage the requirements of every authority having jurisdiction over our various activities and to comply with
their varying standards. Many of these laws and regulations are complex, change frequently, involve significant judgment
and have become more stringent over time. Any changes to existing regulations or adoption of new regulations may result
in significant additional expense to us or our customers. For example, some communities and cities, like Berkeley, CA,
have banned new natural gas hook-ups. Further, from time to time, as part of the regular evaluation of our operations,
including newly acquired or developing operations, we may be subject to compliance audits by regulatory authorities,
which may distract management from our revenue-generating activities and involve significant costs and use of other
resources. Also, we often need to obtain facility permits or licenses to address, among other things, storm water or
wastewater discharges, waste handling and air emissions in connection with our operations, which may subject us to
onerous or costly permitting conditions or delays if permits cannot be timely obtained.
Our failure to comply with any applicable laws and regulations could result in a variety of administrative, civil and
criminal enforcement measures, including, among others, assessment of monetary penalties, imposition of corrective
requirements or prohibition from providing services to government entities. If any of these enforcement measures were
imposed on us, our business, financial condition and performance could be negatively affected.
We may from time to time pursue acquisitions, divestitures, investments or other strategic relationships or transactions,
which could fail to meet expectations or otherwise harm our business.
We may acquire or invest in other companies or businesses or pursue other strategic transactions or relationships, such
as joint ventures, collaborations, divestitures or other similar arrangements. For example, in March 2017 we completed
the BP Transaction, in December 2017 we completed the CEC Combination, and in October 2018 and January 2019 we
established arrangements with THUSA and others to launch the Zero Now truck financing program.
These strategic transactions and relationships and any others we may pursue in the future involve numerous risks, any
of which could harm our business, performance and liquidity, including, among others:
• Difficulties integrating the operations, personnel, contracts, service providers and technologies of an acquired
company or partner;
• Diversion of financial and management resources from existing operations or alternative acquisition, investment,
strategic or other opportunities;
23
• Failure to realize the anticipated synergies or other benefits of a transaction or relationship;
• Failure to identify all of the operating problems, liabilities, shortcomings or other challenges associated with a
company or asset we may partner with, invest in or acquire, including issues related to regulatory compliance
practices, revenue recognition or other accounting policies, intellectual property rights, employee, customer or
vendor relationships, or differing business strategies, approaches, cultures or goals;
• Risks of entering new customer or geographic markets in which we may have limited or no experience, including,
among others, challenges satisfying differing customer demands and preferences and complying with differing
laws and regulations, as well as risks related to political and economic instability in some regions, trade
restrictions or barriers and currency exchange or repatriation uncertainties;
• Potential loss of an acquired company’s or partner’s key employees, customers or vendors in the event of an
acquisition or investment, or potential loss of our assets (and their associated revenue streams), employees or
customers in the event of a divestiture or other strategic transaction;
• Risks associated with any joint venture or other collaboration relationship we may pursue, including as a result
of our relinquishing of some degree of control over the assets, technologies or businesses that are the subject of
the joint venture or collaboration, or as a result of our partners having business goals and interests that are not
aligned with ours or being unable or unwilling to fulfill their obligations in the relationship;
•
Incurrence of substantial costs or debt or equity dilution to fund an acquisition, investment or other transaction
or relationship, and any inability to generate sufficient revenue from the transaction or relationship to offset such
costs;
• Possible write-offs or impairment charges relating to any businesses we partner with, invest in or acquire; and
• The occurrence of many of the risks described above if we fail to accurately predict trends in our key markets,
which could lead us to neglect opportunities that ultimately capitalize on these trends or, conversely, pursue
transactions that do not best serve our markets or customers over the long term.
Our results of operations fluctuate significantly and are difficult to predict.
Our results of operations have historically experienced, and may continue to experience, significant fluctuations as a
result of a variety of factors, including, among others, the amount and timing of our natural gas vehicle fuel sales, station
construction sales, sales of RINs and LCFS Credits and recognition of government credits, grants and incentives, such as
AFTC (for example, we recorded all of the AFTC revenue associated with our vehicle fuel sales made in 2017 during the
first quarter of 2018, and we recorded all of the AFTC revenue associated with our vehicles fuel sales made in 2018 and
2019 in the fourth quarter of 2019); fluctuations in commodity, station construction and labor costs and natural gas, RIN
and LCFS Credit prices; variations in the fair value of certain of our derivative instruments that are recorded in revenue;
the amount and timing of our billing, collections and liability payments; and the other factors described in these risk factors.
Our performance in certain periods has also been affected by transactions or events that have resulted in significant
cash or non-cash gains or losses. For example, our results for 2017 were positively affected by gains related to repurchases
or retirements of our outstanding convertible debt at a discount and by a gain related to the BP Transaction, but were also
negatively affected by significant charges in connection with our closure of certain fueling stations, the decreased operating
performance of our former natural gas fueling compressor manufacturing business, our determination of an impairment of
assets as a result of the foregoing, and certain other actions. These or other similar gains or losses may not recur regularly,
in the same amounts or at all in future periods.
These significant fluctuations in our operating results may render period-to-period comparisons less meaningful, and
investors in our securities should not rely on the results of one period as an indicator of performance in any other period.
Additionally, these fluctuations in our operating results could cause our performance in any period to fall below the
24
financial guidance we may have provided to the public or the estimates and projections of the investment community,
which could negatively affect the price of our common stock.
We depend on key people to generate and oversee our strategies and operate our business, and our business could be
harmed if we are unable to retain these key people.
We believe our future success is dependent on the contributions of certain key people, including our executive officers
and directors. In many cases, we believe these individuals’ knowledge of our business and experience in our industry
would be difficult to replace. As a result, and due to the high levels of competition for talent in our industry, we may incur
significant costs to try to retain these key people. All of our employees, however, including our management team, are
permitted to terminate their employment relationships with us at any time, and any of our directors could resign at any
time or fail to be re-elected by our stockholders on an annual basis. If we are unable to retain our key people, or if these
individuals leave our Company and we are unable to attract and successfully integrate quality replacements in a timely
manner and on reasonable terms, our business, operating results and financial condition could be harmed.
Natural gas purchase and sale commitments may exceed demand or supply, as applicable, which could cause our costs
relative to our revenue to increase.
We are a party to two long-term natural gas purchase agreements with a take-or-pay commitment, and we may enter
into additional similar contracts in the future. These take-or-pay commitments require us to pay for the natural gas we have
agreed to purchase, irrespective of whether we sell the gas. If the market for natural gas as a vehicle fuel declines or fails
to develop as we anticipate, if we lose natural gas vehicle fueling customers, or if demand under any existing or future
sales contract diminishes, these take-or-pay commitments may exceed our natural gas demand. In addition, we are involved
in various firm commitment natural gas supply arrangements, and we may establish additional similar arrangements in the
future. These arrangements require us to supply certain volumes of natural gas over specified periods of time, and subject
us to deficiency payments or other penalties if we are unable to deliver the committed volumes as and when required. If
we fail to generate sufficient demand for our take-or-pay purchase commitments or satisfy our firm supply commitments,
our supply costs or operating expenses could increase without a corresponding increase in revenue, which could negatively
affect our margins, performance and liquidity.
We provide financing to fleet customers for natural gas vehicles, which exposes our business to credit risks.
We directly lend to certain qualifying customers a portion, and occasionally all, of the purchase price of natural gas
vehicles they agree to buy. This direct financing is in addition to our funding of the incremental cost of natural gas heavy-
duty trucks purchased or leased in our Zero Now truck financing program. These financing activities involve a number of
risks, including general credit risks associated with equipment finance relationships. For example, financed equipment
often consists mostly of vehicles, which are mobile and easily damaged, lost or stolen. In addition, the borrower may
default on payments, enter bankruptcy proceedings or liquidate. The materialization of any of these risks could harm our
vehicle finance business and our results of operations and liquidity.
Our warranty reserves may not adequately cover our warranty obligations, which could result in unexpected costs.
We provide product warranties with varying terms and durations for the stations we build and sell, and we establish
reserves for the estimated liability associated with these warranties. Our warranty reserves are based on historical trends
and any specifically identified warranty issues known to us, and the amounts estimated for these reserves could differ
materially from the warranty costs we may actually incur. We would be adversely affected by an increase in the rate or
volume of warranty claims or the amounts involved in warranty claims, any of which could increase our costs beyond our
established reserves and cause our cash position and financial condition to suffer.
We rely on information technology in our operations, and any material failure, inadequacy, interruption or security
failure of that technology could harm our business.
Increased global IT security threats and more sophisticated and targeted computer crime pose a risk to the security of
our systems and networks and the confidentiality, availability and integrity of our data. There have been several recent,
25
highly publicized cases in which organizations of various types and sizes have reported the unauthorized disclosure of
customer or other confidential information, as well as cyberattacks involving the dissemination, theft and destruction of
corporate information, intellectual property, cash or other valuable assets. There have also been several highly publicized
cases in which hackers have requested “ransom” payments in exchange for not disclosing customer or other confidential
information or for not disabling the target company’s computer or other systems. Implementing security measures designed
to prevent, detect, mitigate or correct these or other IT security threats involves significant costs. Although we have taken
steps to protect the security of our information systems and the data maintained in those systems, we have, from time to
time, experienced threats to our data and systems, including malware and computer virus attacks and it is possible that in
the future our safety and security measures will not prevent the systems’ improper functioning or damage, or the improper
access or disclosure of personally identifiable information such as in the event of cyberattacks. Any IT security threats that
are successful against our security measures could, depending on their nature and scope, lead to the compromise of
confidential information, improper use of our systems and networks, manipulation and destruction of data, operational
disruptions and substantial financial outlays. Further, a cyberattack could occur and persist for an extended period of time
without detection, and an investigation of any successful cyberattack would likely require significant time, costs and other
resources to complete. We may be required to expend significant financial resources to protect against or to remediate
such cyberattacks. In addition, our technology infrastructure and information systems are vulnerable to damage or
interruption from natural disasters, power loss and telecommunications failures. Any failure to maintain proper function,
security and availability of our information systems and the data maintained in those systems could interrupt our
operations, damage our reputation, subject us to liability claims or regulatory penalties, harm our business relationships or
increase our security and insurance costs, which could have a material adverse effect on our business, financial condition
and results of operations.
Global climate change may increase the frequency and severity of weather events and the losses resulting from these
events, which could have a material adverse effect on our business and the markets in which we operate.
Over the past several years, changing weather patterns and climatic conditions have added to the unpredictability and
frequency of natural disasters in certain parts of the world and have created additional uncertainty as to future trends. We
cannot predict whether or to what extent natural disasters may occur or increase, nor can we predict the effect such events
will have on our operations or the geographic markets in which we operate; however, any increased frequency or severity
of these events could increase their overall negative effect on economic conditions in these regions and could also directly
affect our operations if our fueling stations, our LNG plants or our customers’ operations are damaged or otherwise
subjected to limited operations as a result of such an event. The occurrence of any of these risks could negatively affect
our business, performance and liquidity, and could also cause the price of our common stock to decline.
We may not generate sufficient cash flow from our business to pay our debt.
We have material indebtedness, and we are permitted to incur significant additional debt under the agreements we
established in connection with our Zero Now truck financing program. Our outstanding and permitted indebtedness could
make us more vulnerable to adverse changes in general U.S. and worldwide economic, regulatory and competitive
conditions, limit our flexibility to plan for or react to changes in our business or industry, place us at a disadvantage
compared to our competitors that have less debt or limit our ability to borrow or otherwise raise additional capital as
needed.
Our payments of amounts owed under our agreements related to our Zero Now program and various other debt
instruments will reduce our cash resources available for other purposes, including pursuing strategic initiatives,
transactions or other opportunities, satisfying our other commitments and generally supporting our operations. Moreover,
our ability to make these payments depends on our future performance, which is subject to economic, financial,
competitive and other factors, including those described in these risk factors, and many of which are beyond our control.
Our business may not generate sufficient cash from operations to service our debt.
If we cannot meet our debt obligations from our operating cash flows, we may pursue one or more alternative
measures. For instance, we are permitted to issue up to 14.0 million shares of our common stock to repay part of the
outstanding principal amount of our outstanding convertible notes due June 2020. Any repayment of our debt with equity,
however, would dilute the ownership interests of our existing stockholders. Additionally, because the agreements
26
governing much of our existing indebtedness contain minimal restrictions on our ability to incur additional debt and do
not require us to maintain financial ratios or specified levels of net worth or liquidity, we may seek capital from other
sources to service our debt, such as selling assets, restructuring or refinancing our existing debt or obtaining additional
equity or debt financing. Our ability to engage in any of these activities, if we decide to do so, would depend on the capital
markets and the state of our industry, business and financial condition at the time, and could also subject us to significant
risks, which are discussed elsewhere in these risk factors. Moreover, we may not be able to obtain any additional capital
we may pursue on desirable terms, at a desirable time or at all. Any failure to pay our debts when due could result in a
default on our debt obligations. In addition, certain of our debt agreements contain restrictive covenants, and any failure
by us to comply with these covenants could also cause us to be in default under these agreements.
In the event of any default on our debt obligations, the holders of the indebtedness could, among other things, declare
all amounts owed immediately due and payable. Additionally, with respect to any amounts owed under our term credit
agreement that are paid by THUSA pursuant to its guaranty rather than by us, THUSA would be permitted to take direct
possession of funds paid by fleet operators under any fuel supply agreements we establish in connection with our Zero
Now truck financing program. Any such declaration or possession of funds could deplete all or a large portion of our
available cash flow, and thereby reduce the amount of cash available to pursue our business plans or force us into
bankruptcy or liquidation.
Risks Related to Our Common Stock
A significant portion of our common stock is beneficially owned by a single stockholder that may have interests that
differ from yours and that is able to exert significant influence over our corporate decisions, including a change of
control.
Following our issuance and sale of our common stock to Total in June 2018, Total holds approximately 25% of our
outstanding shares of common stock and the largest ownership position of our Company. In addition, TOTAL was granted
certain special rights that our other stockholders do not have in connection with its acquisition of this ownership position,
including the right to designate two individuals to serve as directors of our Company and a third individual to serve as an
observer on certain of our board committees. TOTAL or other large stockholders may be able to influence or control
matters requiring approval by our stockholders, including the election of directors and mergers, acquisitions or other
extraordinary transactions. TOTAL, however, may have interests that differ from yours and may vote or otherwise act in
ways with which you disagree or that may be adverse to your interests. A concentration of stock ownership may also have
the effect of delaying, preventing or deterring a change of control of our Company, which could deprive our stockholders
of an opportunity to receive a premium for their shares of our common stock as part of a sale of our Company and could
affect the market price of our common stock. Conversely, such a concentration of stock ownership may facilitate a change
of control under terms you and other stockholders may not find favorable or at a time when you and other stockholders
may prefer not to sell.
Sales of our common stock, or the perception that such sales may occur, could cause the market price of our stock to
drop significantly, regardless of the state of our business.
All outstanding shares of our common stock are eligible for sale in the public market, subject in certain cases to the
requirements of Rule 144 under the Securities Act. Also, shares of our common stock that may be issued upon the exercise,
vesting or conversion of our outstanding stock options, restricted stock units and convertible notes may be eligible for sale
in the public market, to the extent permitted by Rule 144 and the provisions of the applicable stock option, restricted stock
unit and convertible note agreements or if such shares have been registered under the Securities Act. For instance, we filed
a registration statement with the SEC to cover the resale of the 50,856,296 shares of our common stock issued and sold to
Total, which such registration statement was declared effect in August 2018. We have also registered for resale all shares
of our common stock issuable upon conversion of the 7.5% notes originally issued to T. Boone Pickens and Green Energy
Investment Holdings, LLC in June 2013. See Note 13 for additional information. If these shares are sold, or if it is
perceived that they may be sold, in the public market, the trading price of our common stock could decline.
27
The price of our common stock may continue to fluctuate significantly, and you could lose all or part of your investment.
The market price of our common stock has experienced, and may continue to experience, significant volatility. Factors
that may cause volatility in the price of our common stock, many of which are beyond our control, include, among others:
• The factors that may influence the adoption of natural gas as a vehicle fuel, as discussed elsewhere in these risk
factors;
• Our ability to implement our business plans and initiatives, such as our Zero Now truck financing program, and
their anticipated, perceived or actual level of success;
• Failure to meet or exceed any financial guidance we have provided to the public or the estimates and projections
of the investment community;
• The market’s perception of the success and importance of any of our acquisitions, divestitures, investments or
other strategic relationships or transactions;
• The amount of and timing of sales of, and prices for, RINs and LCFS Credits;
• Changes in political, regulatory, economic and market conditions;
• Changes to our management, including officer or director departures, replacements or other changes;
• Our issuance of additional shares of our common stock (or securities convertible into or exchangeable for our
common stock);
• A change in the trading volume of our common stock; and
• The other risks described in these risk factors.
In addition, the securities markets have from time to time experienced significant price and volume fluctuations that
are unrelated to the operating performance of particular companies, but which have affected the market prices of these
companies’ securities. These market fluctuations may also materially and adversely affect the market price of our common
stock.
Volatility or declines in the market price of our common stock could have other negative consequences, including,
among others, further impairments to our assets (following the asset impairment charges we recorded in the third and
fourth quarters of 2017 related to our former natural gas fueling compressor manufacturing business and our closure of
certain fueling stations), potential impairments to our goodwill and a reduced ability to use our common stock for capital-
raising, acquisitions or other purposes. The occurrence of any of these risks could materially and adversely affect our
financial condition, results of operations and liquidity and could cause further declines in the market price of our common
stock.
Item 1B. Unresolved Staff Comments.
None.
Item 2. Properties.
Our corporate headquarters are located at 4675 MacArthur Court, Suite 800, Newport Beach, California 92660, where
we occupy approximately 48,000 square feet of office space. Our lease for this facility expires in June 2021.
28
We own and operate the Boron 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.
We own and operate the Pickens Plant located in Willis, Texas, approximately 50 miles north of Houston. We own
approximately 24 acres of land on which this plant is situated, along with approximately 34 acres surrounding the plant.
Item 3. Legal Proceedings.
From time to time, we may become involved in various legal proceedings that arise in the ordinary course of our
business, including lawsuits, claims, audits, government enforcement actions and related matters. It is not possible to
predict when or if these proceedings may arise, nor is it possible to predict the outcome of any proceedings that do arise,
including, among other things, the amount or timing of any liabilities we may incur, and any such proceedings could have
a material effect on us regardless of outcome. In the opinion of management, however, we are not a party, and our
properties are not subject, to any pending legal proceedings that are material to us.
Item 4. Mine Safety Disclosures.
None.
29
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity
Securities.
PART II
Market Information
Our common stock trades on The Nasdaq Global Select Market under the symbol “CLNE.”
Holders
There were approximately 53 holders of record of our common stock as of March 4, 2020.
Performance Graph
This performance graph shall not be deemed “soliciting material” or “filed” with the SEC or subject to Regulation
14A or 14C or to the liabilities of Section 18 of the Exchange Act, or incorporated by reference into any filing under the
Securities Act or the Exchange Act, except to the extent that we specifically request that such information be treated as
soliciting material or specifically incorporate it by reference into such a filing. The graph is required by applicable rules of
the SEC and is not intended to forecast, predict or be indicative of the possible future performance of our common stock.
The following graph compares the five-year total return to holders of our common stock relative to the cumulative
total returns of the Nasdaq Global Market Index and the Russell 2000 Index. The graph assumes that $100 was invested
in our common stock and on each of these indices at the close of market on December 31, 2014 (the last trading day before
the beginning of our fifth preceding fiscal year). We chose to include the Russell 2000 Index because it includes issuers
with similar market capitalizations as us and due to the lack of a comparable industry or line-of-business index or peer
30
group, as we are the only actively traded public company whose only line of business is to sell natural gas for use as a
vehicle fuel and the associated equipment and services necessary to use natural gas as a vehicle fuel.
150.00%
100.00%
50.00%
0.00%
-50.00%
-100.00%
Clean Energy Fuels Corp. (NasdaqGS:CLNE) - Share Pricing
Russell 2000 Index (^RUT) - Index Value
NASDAQ Composite Index (^COMP) - Index Value
Item 6. Selected Financial Data.
The following selected historical consolidated financial data should be read together with Item 7. Management’s
Discussion and Analysis of Financial Condition and Results of Operations and our consolidated financial statements and
the related notes included in this report, which describe, among other things, factors that could materially affect the
comparability of the data reflected below. Additionally, see Item 1A. Risk Factors and Item 7. Management’s Discussion
and Analysis of Financial Condition and Results of Operations for discussions of material uncertainties that might cause
the data reflected below not to be indicative of our future financial condition or results of operations.
The consolidated statements of operations data for the years ended December 31, 2017, 2018 and 2019 and the
consolidated balance sheet data as of December 31, 2018 and 2019 are derived from our audited consolidated financial
statements included in this report. The consolidated statements of operations data for the years ended December 31, 2015
and 2016 and the consolidated balance sheet data as of December 31, 2015, 2016 and 2017 are derived from our audited
consolidated financial statements that are not included in this report.
During the year ended December 31, 2017, we sold certain assets to BP in the BP Transaction, and combined our
natural gas compressor subsidiary, CEC, with the natural gas compressor subsidiaries of Landi Renzno S.p.A., in a new
company known as “SAFE&CEC S.r.l.” (referred to as the “CEC Combination”). In addition, the results of the divested
companies are included in our consolidated financial statements prior to their respective dates of divestiture. The
31
consolidated balance sheet data as of December 31, 2019 reflects the modified retrospective transition method adoption of
Accounting Standards Update (“ASU”) 2016-02, Leases (842).
2015
Year Ended December 31,
2016
2017
(In thousands, except share data)
2018
2019
Statement of Operations Data:
Total revenue (1)
Operating income (loss)
Net income (loss)
Basic income (loss) per share
Diluted income (loss) per share
(1) Total revenue includes the following amounts:
(41,623)
(135,458)
$ 384,320 $ 402,656 $ 341,599 $ 346,419 $ 344,065
9,928
13,259
0.10
0.10
3,895
(9,183)
(0.02) $
(0.02) $
(134,447)
(81,391)
(17,637)
(13,724)
(0.53) $
(0.53) $
(0.10) $
(0.10) $
(1.47) $
(1.47) $
$
$
(In thousands)
Alternative fuels tax credits (AFTC)
2015
30,986 $
$
Year Ended December 31,
2017
2016
26,638 $ — $
2018
26,729 $
2019
47,123
Balance Sheet Data:
Cash and cash equivalents and short-term investments
Restricted cash, short-term
Restricted cash, long-term
Working capital
Total assets
Total debt inclusive of capital and finance lease
obligations (1)
Total Clean Energy Fuels Corp. stockholders' equity
December 31,
2015
2016
2017
2018
2019
(In thousands)
$
146,668 $ 109,837 $ 177,543 $ 95,490 $ 106,136
15
4,000
145,347 131,230
699,082 777,085
1,127
—
101,597
791,912
6,996
—
172,542
897,257
4,240
—
82,773
1,000,528
780
4,000
567,150
302,552
312,376
468,865
260,087
426,990
84,184
92,215
507,998 533,408
(1) 2016, 2017, 2018, and 2019 amounts include debt issuance costs as a deduction from the carrying amount of the related liability.
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
The following Management’s Discussion and Analysis of Financial Condition and Results of Operations (this
discussion, as well as discussions under the same heading in our other periodic reports, are referred to as the “MD&A”)
should be read together with our audited consolidated financial statements and the related notes included in this report,
and all cross references to notes included in this MD&A refer to the identified note in such consolidated financial
statements. This section of the Form 10-K generally discusses 2019 and 2018 items and year-to-year comparisons of 2019
to 2018. Discussions of 2017 items and year-to-year comparisons of 2018 and 2017 that are not included in this Form 10-K
can be found in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II,
Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2018, filed with the SEC on March 12, 2019.
Cautionary Note Regarding Forward-Looking Statements
This MD&A contains forward-looking statements. See the discussion about these statements under “Cautionary
Note Regarding Forward-Looking Statements” at the beginning of this report.
Overview
We are North America’s leading provider of the cleanest fuel for the transportation market, based on the number of
stations operated and the amount of gasoline gallon equivalents (“GGEs”) of RNG, CNG and LNG delivered. Through
our sales of Redeem™ RNG, which is derived from biogenic methane produced by the breakdown of organic waste, we
32
help thousands of vehicles, from airport shuttles to city buses to waste and heavy-duty trucks, to reduce their amount of
climate-harming greenhouse gas by at least 70% and up to 300% depending on the source of the RNG feedstock. Redeem
is delivered through compressed natural gas (CNG) and liquefied natural gas (LNG); sales of our Redeem RNG have
increased dramatically, from 13.0 million GGEs in 2013 (the year we introduced Redeem RNG to the vehicle fuel market)
to 143.3 million GGEs in 2019.
Our principal business is supplying RNG, CNG and LNG for medium and heavy-duty vehicles and providing O&M
services for public and private vehicle fleet customer stations. As a comprehensive solution provider, we also design, build,
operate and maintain fueling stations; sell and service natural gas fueling compressors and other equipment used in CNG
stations and LNG stations; offer assessment, design and modification solutions to provide operators with code-compliant
service and maintenance facilities for natural gas vehicle fleets; transport and sell CNG and LNG via “virtual” natural gas
pipelines and interconnects; procure and sell RNG; sell tradable credits we generate by selling RNG and conventional
natural gas as a vehicle fuel, including RIN Credits and LCFS Credits; help our customers acquire and finance natural gas
vehicles; and obtain federal, state and local tax credits, grants and incentives. In addition, before March 31, 2017, we
produced RNG at our own production facilities (which we sold, along with certain of our other RNG production assets, in
the BP Transaction), and before December 29, 2017, we manufactured natural gas fueling compressors and other
equipment used in CNG stations (which we combined with another company’s natural gas fueling compressor
manufacturing business in a newly formed joint venture, in the CEC Combination).
We serve fleet vehicle operators in a variety of markets, including heavy-duty trucking, airports, refuse, public transit,
industrial and institutional energy users, and government fleets. We believe these fleet markets will continue to present a
growth opportunity for natural gas vehicle fuel for the foreseeable future. As of December 31, 2019, we serve over 1,000
fleet customers operating over 48,000 natural gas vehicles, and we own, operate or supply approximately 550 natural gas
fueling stations in 41 states in the United States and four provinces in Canada.
Performance Overview
This performance overview discusses matters on which our management focuses in evaluating our financial condition
and operating results.
Sources of Revenue
The following table represents our sources of revenue:
Revenue (in millions)
Volume-related (1)
Compressor sales (2)
Station construction sales
AFTC (3)
Other (4)
Total
$
$
$
2017
264.9 $
Year Ended December 31,
2018
286.7
—
25.5
26.7
7.5
346.4
23.5
51.9
—
1.3
341.6 $
$
2019
273.6
—
23.1
47.1
0.3
344.1
(1) Our volume-related revenue primarily consists of sales of RNG, CNG and LNG fuel, performance of O&M services, and sales of RINs and LCFS
Credits in addition to changes in fair value of our derivative instruments. More information about our volume of fuel and O&M services delivered
in the periods is included below under “Key Operating Data,” and more information about our derivative instruments, which consist of commodity
33
swap and fueling contracts, is included below under “2018-2020 Developments.” Additionally, a discussion of volume-related revenue is included
below under “Results of Operations”. The following table summarizes our volume-related revenue in the periods:
Revenue (in millions)
Fuel sales and performance of O&M services
Change in fair value of derivative instruments (a)
RIN Credits (b)
LCFS Credits (b) (c)
Total volume-related revenue
$
$
Year Ended December 31,
2018
249.0
10.3
16.4
11.0
286.7
2017
240.8 $
—
21.6
2.5
264.9 $
$
$
2019
248.8
(6.6)
18.1
13.3
273.6
a.
The change in fair value of derivative instruments is related to the Company’s commodity swap and customer fueling contracts. The amounts
are classified as revenue because the Company’s commodity swap contracts are used to economically offset the risk associated with the
diesel-to-natural gas price spread resulting from customer fueling contracts under the Company’s Zero Now truck financing program.
b. Revenue from sales of RINs and LCFS Credits decreased after the first quarter of 2017 due to the effects of the BP Transaction. See “Key
Trends” below for more information.
c. We recognized no revenue from sales of LCFS Credits during the third and fourth quarters of 2017 because (i) the majority of the LCFS
Credits we had generated were sold in the BP Transaction and (ii) we could not sell our remaining LCFS Credits due to restrictions imposed
on our credit account pending completion of an ongoing administrative review by CARB, which was completed in November 2017. See “Key
Trends” below for more information.
(2) We completed the CEC Combination on December 29, 2017 (see Note 4). As a result, no revenue for compressor sales has been or will be received
or recorded after that date.
(3) Represents the AFTC, an alternative fuels tax credit, which expired on December 31, 2016, but in February 2018, was reinstated for vehicle fuel
sales made in 2017. In December 2019, the AFTC was reinstated retroactively for vehicle fuels sales made in 2018 through 2020. See “2018-2020
Developments” below for more information.
(4)
Included in other revenue for the years ended December 31, 2017 and 2018 is sales of used natural gas heavy-duty trucks of $0.6 million and $7.5
million, respectively, which we purchased in 2017 and 2018.
Key Operating Data
In evaluating our operating performance, our management focuses primarily on: (1) the amount of RNG, CNG and
LNG gasoline gallon equivalents delivered (which we define as (i) the volume of gasoline gallon equivalents we sell to
our customers as fuel, plus (ii) the volume of gasoline gallon equivalents dispensed at facilities we do not own but where
we provide O&M services on a per-gallon or fixed fee basis, plus (iii) our proportionate share of the gasoline gallon
equivalents sold as CNG by our joint venture with Mansfield Ventures, LLC called Mansfield Clean Energy Partners, LLC
(“MCEP”), plus (iv) for periods before completion of the BP Transaction, our proportionate share (as applicable) of the
gasoline gallon equivalents of RNG produced and sold as pipeline quality natural gas by our former RNG production
facilities, which we sold in the BP Transaction), (2) our station construction cost of sales, (3) our gross margin (which we
define as revenue minus cost of sales), and (4) net income (loss) attributable to us. The following tables present our key
operating data for the years ended December 31, 2017, 2018, and 2019:
Gasoline gallon equivalent delivered (in millions)
CNG (1)
LNG
Non-vehicle RNG (2)
Total
Year Ended December 31,
2018
299.5
66.0
—
365.5
2017
283.4
66.1
1.9
351.4
2019
335.7
65.1
—
400.8
RNG sold as vehicle fuel under the brand name RedeemTM is included in the CNG or LNG amounts in the table above as
applicable based on the form in which it was sold. GGEs of Redeem sold for the years ended December 31, 2017, 2018
and 2019 were as follows:
34
Gasoline gallon equivalent delivered (in millions)
RedeemTM
Gasoline gallon equivalent delivered (in millions)
O&M services
Fuel (1)
Fuel and O&M services (3)
Total
2017
Year Ended December 31,
2018
110.1
78.5
2019
143.3
Year Ended December 31,
2018
206.1
133.6
25.8
365.5
2017
199.5
127.3
24.6
351.4
2019
211.4
162.4
27.0
400.8
Other operating data (in millions)
Station construction cost of sales
Gross margin (4) (5) (6)
Net income (loss) attributable to Clean Energy Fuels. Corp (4)
Year Ended December 31,
2018
2019
2017
$
$
$
47.0 $
85.8 $
(79.2) $
25.1 $
133.5 $
(3.8) $
23.5
132.0
20.4
(1) As noted above, amounts include our proportionate share of the GGEs sold as CNG by our joint venture MCEP. GGEs sold by this joint venture
were 0.5 million, 0.5 million and 0.4 million for the years ended December 31, 2017, 2018 and 2019, respectively.
(2) Represents RNG sold as non-vehicle fuel. RNG sold as vehicle fuel, is sold under the brand name Redeem™ and is included in this table in the
CNG or LNG amounts as applicable based on the form in which it was sold.
(3) Represents gasoline gallon equivalents at stations where we provide both fuel and O&M services.
(4)
Includes the following amounts of AFTC revenue: $0.0 million, $26.7 million and $47.1 million for the years ended December 31, 2017, 2018,
and 2019, respectively.
(5) For the year ended December 31, 2017, gross margin includes an inventory valuation provision of $13.2 million. See Note 3 for more information
regarding the inventory valuation provision.
(6) For the years ended December 31, 2018 and 2019, gross margin includes an unrealized gain (loss) from the change in fair value of commodity
swap and customer contracts of $10.3 million and $(6.6) million, respectively. See Note 8 for more information regarding the commodity swap
and customer contracts.
2018 -2020 Developments
Zero Now Truck Financing Program. We launched the Zero Now truck financing program, which is intended to
facilitate and increase the deployment of commercially available ultra-low NOx natural gas heavy-duty trucks in the United
States and encourage these operators to fuel their trucks at our stations. The Zero Now program is unique and complex,
and has involved our entry into various arrangements in order to launch the program, including a term credit agreement
for delayed draw loans of up to $100.0 million; a credit support agreement with THUSA, a wholly owned subsidiary of
TOTAL, under which THUSA has guaranteed our obligations under the term credit agreement in exchange for a quarterly
fee; and commodity swap arrangements with an affiliate of THUSA and TOTAL covering five million diesel gallons of
natural gas fuel volume annually from April 2019 through June 2024, which are intended to manage diesel price fluctuation
risks related to the natural gas fuel supply commitments we expect to make in our anticipated fueling agreements with
fleet operators that participate in the Zero Now program. See the disclosure under “Customer Markets-Zero Now” in
“Item 1. Business” of this report for information about these agreements and the structure of the program.
Debt Repurchase. In December 2018, we purchased from the holders thereof all outstanding 7.5% Convertible
Notes due July 2019, having an aggregate outstanding principal amount of $50.0 million, for a cash purchase price of
$50.5 million. Upon such purchase, all such notes were surrendered and canceled in full and we have no further obligations
under these notes. As a result of the early retirement of these notes we saved $1.7 million in interest expense in 2019. See
Note 13 for more information about our outstanding debt.
35
Expanded BP RNG Supply Agreement. In October 2018, our supply agreement with BP was amended to extend the
term and add additional RNG supply. We share with BP in the RINs and LCFS Credits generated from the increased RNG
supply sold through our vehicle fueling infrastructure and to other customers.
Full Cash Repayment of 5.25% Notes. On October 1, 2018, we paid to the holders of our 5.25% Convertible Senior
Notes due October 2018, in cash, all amounts then owed under the notes, totaling an aggregate of $110.5 million in
principal amount plus $2.9 million in accrued and unpaid interest. Upon such payment, all such notes were surrendered
and canceled in full and we have no further obligations under these notes.
Total Private Placement. On May 9, 2018, we entered into a stock purchase agreement with Total Marketing Services,
S.A. (“Total”), a wholly owned subsidiary of TOTAL, for the sale and issuance to Total of up to 50,856,296 shares of our
common stock for a per share purchase price of $1.64 and an aggregate purchase price of $83.4 million, all in a private
placement (the “Total Private Placement”). The Total Private Placement closed on June 13, 2018, upon the satisfaction of
all conditions to closing. We used the net proceeds from the Total Private Placement for working capital and general
corporate purposes, which included retiring a portion of our outstanding indebtedness.
The agreements related to the Total Private Placement also contain representations, warranties and covenants made
by us and Total regarding, among other matters, certain director designation rights we have granted to Total (along with
undertakings by certain of our stockholders, including all of our directors and executive officers, to vote their shares in
favor of such director designees in future elections of directors), certain registration rights we have granted to Total for the
shares that were issued and sold, certain limitations on Total’s purchase of additional securities of our Company without
the approval of our board of directors, and various other matters that are customary for transactions of this nature.
AFTC. The AFTC, which had previously expired on December 31, 2016, was reinstated on February 9, 2018 to apply
to vehicle fuel sales made from January 1, 2017 through December 31, 2017. As a result, all AFTC revenue for vehicle
fuel we sold in the 2017 calendar year, which totaled $25.2 million, was recognized and collected during the year ended
December 31, 2018. In addition, during the year ended December 31, 2018, the Internal Revenue Service approved, and
we recognized as revenue, $1.5 million of AFTC credit claims related to prior years. On December 20, 2019, AFTC was
retroactively extended beginning January 1, 2018 through December 31, 2020. As a result, AFTC revenue for vehicle fuel
we sold in 2018 and 2019, which totaled $47.1 million, was recognized during the year ended December 31, 2019. The
AFTC credit for 2017, 2018 and 2019 was equal to $0.50 per gasoline gallon equivalent of CNG that we sold as vehicle
fuel, and $0.50 per diesel gallon of LNG that we sold as vehicle fuel. AFTC is currently available through December 31,
2020 and may not be reinstated for vehicle fuel sales made after that date.
NG Advantage. During the year ended December 31, 2019, we loaned to our subsidiary NG Advantage, LLC (“NG
Advantage”) an aggregate of $26.7 million, all of which remained outstanding as of December 31, 2019. All such debt
was governed by the terms of a delayed draw convertible note that permitted NG Advantage to draw up to $26.7 million,
subject to certain conditions. All outstanding principal under the note bore interest at a rate of 12.0% per annum, and all
unpaid principal and accrued interest under the note was due on the earlier of December 31, 2019, subject to extension at
the Company's discretion, or the occurrence of an event of default (subject to notice requirements and cure periods in
certain circumstances). In connection with this debt, on June 28, 2019 and November 27, 2019, NG Advantage issued us
warrants to purchase 86,879 and 2,000,000 common units, respectively. These intercompany transactions have been
eliminated in consolidation.
In February 2020, we converted the principal and accrued interest under the convertible promissory note into common
units of NG Advantage resulting in an increase in our controlling interest in NG Advantage to 93.2%.
See Notes 5 and 23 for additional information regarding the convertible promissory note.
Debt Level and Debt Compliance
As of December 31, 2019, we had total indebtedness, excluding finance lease obligations, of $89.1 million in principal
amount, of which approximately $56.1 million is expected to become due in 2020. Certain of the agreements governing
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our outstanding debt, which are discussed in Note 13, have certain non-financial covenants with which we must comply.
As of December 31, 2019, we were in compliance with all of these covenants.
Key Trends
Market for RNG, CNG and LNG as a Vehicle Fuel
According to CARB, RNG and conventional natural gas are cleaner than gasoline and diesel fuel based on the
greenhouse gas emissions produced by vehicles operated by these fuels. Additionally, RNG and conventional natural gas
are generally less expensive than gasoline and diesel on an energy equivalent basis. According to the U.S. Energy
Information Administration, demand for renewable and conventional natural gas fuels in the United States has increased
in recent years and is expected to continue to increase. We expect our sales of Redeem RNG and conventional natural gas
to grow as more companies look to operate in an increasingly sustainable way. In addition to pressure from politicians,
regulators and non-governmental organizations, the investment community has dramatically stepped up demands on
companies to diminish their contributions to climate change. We believe that RNG is the best tool available today to reduce
climate-harming greenhouse gas and meet sustainability objectives.
The market for natural gas as a vehicle fuel, however, is a relatively new and developing market. As a result, it is
challenging to accurately predict natural gas vehicle fuel demand, in general and in any specific geographic and customer
markets, and consequently our timing and level of investment in particular markets may not be consistent with any growth
in demand in these markets. Further, the new and developing nature of the natural gas vehicles fuel market has led to slow,
volatile or unpredictable growth in many sectors. For example, to date, adoption and deployment of natural gas vehicles,
in general and in certain of our key customer markets, including heavy-duty trucking, have been slower and more limited
than we anticipated. Also, other important markets, including airports, refuse and public transit, have experienced
fluctuations in their natural gas adoption, including slower volume and customer growth in 2018 and 2019 that may
continue. Moreover, adoption of and demand for the different types of natural gas vehicle fuel, including RNG, CNG and
LNG, are subject to significant risks, including decreased LNG volumes in some markets in recent periods that may
continue and may not be sufficiently offset by any increase in demand for RNG or CNG. We believe these market
conditions have contributed to our lower revenue levels in recent periods.
We believe the slow growth and unpredictability of the market for natural gas vehicle fuels has been caused by a
number of factors, including the following:
• Since approximately mid-2014, the prices of oil, gasoline, diesel and natural gas have been lower on average and
more volatile, and these trends may continue. We believe these conditions have contributed to slower and more
limited growth in the demand for natural gas as a vehicle fuel because the price advantage of natural gas compared
to diesel and gasoline has decreased, and we expect adoption of natural gas as a vehicle fuel and growth in our
customer base and revenue will continue to be negatively affected while oil and diesel prices remain low. In
addition, these pricing conditions have led us to reduce the prices we charge some of our customers for CNG and
LNG, which has reduced our profit margins.
•
In recent years, there has been increased focus by some parties, including lawmakers, regulators, policymakers,
environmental and advocacy organizations and other powerful groups, on electric or other alternative vehicles or
vehicle fuels. For example, California lawmakers and regulators have implemented various measures designed to
increase the use of electric, hydrogen and other zero-emission vehicles, including establishing firm goals for the
number of these vehicles operating on state roads by specified dates and enacting various laws and other programs
in support of these goals. Further, there is continued and long-standing support among many of these groups for
gasoline and diesel-powered vehicles. If these groups continue to invest time and money in efforts to promote
non-natural gas fuels or suppress support for natural gas, then publicity or popular sentiment for non-natural gas
vehicle fuels could increase in our key customer markets, which could decrease the growth potential for natural
gas as a vehicle fuel, and government policies and programs in favor of non-natural gas vehicle fuels could be
adopted in place of existing or new programs that promote natural gas, which could reduce the benefits we receive
from these programs.
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• We believe the lack of substantial growth in the heavy-duty trucking market has been driven in large part by
factors outside of our control. For instance, some heavy-duty truck operators have communicated to us that their
primary reluctance to convert to natural gas trucks stems from experience or reputation of unsatisfactory
performance by prior models of heavy-duty truck engines, actual or perceived insufficiencies in the financial
incentives to convert, lack of demand for the conversion from customers and drivers, prioritization of other
competing business concerns and improvements in diesel engine technology. If these conditions continue, then
the growth levels in this market will continue to be low. Although we have launched our Zero Now truck financing
program in an effort to combat certain of these operator concerns, this program may not be successful for a variety
of reasons, in which case our volumes and revenue would not increase. Moreover, the structure of the program,
which involves increasing our debt by potentially material amounts, paying certain interest and other fees (which
will vary in amount but will be owed by us regardless of the level of success of the program), and possibly owing
amounts under the commodity swap arrangements we established in connection with the program, could
negatively affect our liquidity. See the disclosure under “Customer Markets-Zero Now” in “Item 1. Business” of
this report and Note 13 for more information.
To the extent these or other factors have contributed to curtailed demand or slowing growth in the market for natural
gas as a vehicle fuel, we believe they have also contributed to decreases in station construction activity in certain periods,
as the success of this activity is dependent on the success of the natural gas vehicle fuels market generally. Moreover, we
believe these factors have materially contributed to the volatility and overall decline in our stock price and market
capitalization in recent years, which has and could in the future lead to decreased cash flows and indications of asset or
goodwill impairment. If these adverse macroeconomic conditions and other uncertainties in our industry persist, our
financial results and stock price may continue to be adversely affected.
In spite of these market conditions, we believe our key customer markets, including heavy-duty trucking, airports,
refuse, public transit, industrial and institutional energy users and government fleets, are well-suited for the adoption of
natural gas vehicle fuel because they consume relatively high volumes of fuel, refuel at centralized locations or along well-
defined routes and/or are facing increasingly stringent emissions or other environmental requirements. We also expect the
lower greenhouse gas emissions associated with our Redeem vehicle fuel will result in increased demand for this fuel,
resulting in our continued delivery of increasing volumes of Redeem to our vehicle fleet customers. Additionally, we
anticipate that, over time, cities and communities in the United States and Canada will follow large cities in Europe in
banning dirty diesel vehicles. If these projections materialize, we believe there will be growth in the consumption of natural
gas as a vehicle fuel in our key customer and geographic markets, and our goal is to capitalize on this growth if and when
it materializes. In that event, we expect our operating costs and capital expenditures would increase in connection with
any growth of our business in the future.
Our Performance
Overview. Our gross revenue mostly consists of volume-related revenue, compressor and other equipment sales
(before the CEC Combination), station construction sales, and AFTC revenue. Our revenue can vary between periods due
to a variety of factors, including, among others, the amount and timing of natural gas vehicle fuel sales, natural gas prices,
station construction sales, sales of RINs and LCFS Credits, compressor and other equipment sales (before the CEC
Combination), and recognition of government credits, grants and incentives, such as AFTC. In addition, our volume-
related revenue has been and may continue to be subject to increased fluctuations as a result of our entry into certain
commodity swap arrangements in October 2018, because the changes in fair value of these and certain other derivative
instruments, including existing and anticipated fueling contracts under our Zero Now truck financing program, are included
in volume-related revenue.
Our cost of sales can also vary between periods due to a variety of factors, including fluctuations in natural gas prices,
station construction and labor costs, and compressor equipment costs (before the CEC Combination), as well as the other
factors that impact our revenue levels described above.
In addition, our performance in certain periods has been affected by transactions or events that have resulted in
significant cash or non-cash gains or losses. For example, our results for 2017 were positively affected by a gain related
to repurchases and retirements of our outstanding convertible debt at a discount, and a gain related to the BP Transaction,
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but our results for 2017 were negatively affected by significant charges in connection with our closure of certain fueling
stations, the decreased operating performance of our former natural gas fueling compressor manufacturing business, our
determination of an impairment of assets as a result of the foregoing, and certain other actions. These or other similar gains
or losses may not recur regularly, in the same amounts or at all in future periods and, with respect to non-cash gains and
losses, do not impact our liquidity.
In the third and fourth quarters of 2017, we took actions we believe will better align our activities and assets with
current and anticipated market demand. These actions included a workforce reduction and other measures to reduce
overhead costs, which resulted in cash severance costs and certain non-cash stock-based compensation charges; our
decision to close certain of our natural gas fueling stations by the end of 2017, which resulted in an impairment of these
station assets and certain other cash and non-cash charges; our determination that the assets of CEC, our former subsidiary,
were impaired, which resulted in a non-cash charge; and our contribution of CEC to a newly formed joint venture in the
CEC Combination. These actions affected our performance in 2017 as a result of the cash expenses and non-cash
impairment and other charges, which could be repeated if we decide to implement similar measures in the future but may
otherwise limit the comparability of our 2017 results. In addition, these actions will affect our future performance and
financial condition. For instance, our fueling station closures and the CEC Combination have decreased our aggregate
revenue and cost levels, and we expect these lower levels to continue. In addition, our workforce reduction and other
measures to reduce overhead costs have contributed to decreased expenses, particularly selling, general and administrative
expenses, and we expect these lower expense levels will also continue. These actions also led us to record asset impairment
and other cash and non-cash charges in 2017, and we may determine to record this type of asset or goodwill impairment
in future periods due to similar or other events or factors. For example, a sustained decline in our stock price and the
resulting decline of our market capitalization or periods of general volatility in our market capitalization, as we have
experienced in recent periods, could cause our goodwill to become impaired, which could result in material charges and
adversely affect our results of operations.
See “Results of Operations” below for more information about our performance in 2018 and 2019.
Volume. The amount of RNG, CNG and LNG we delivered increased by 9.7% from 2018 to 2019.
In particular, the amount of RNG we sell for vehicle fuel, which is delivered in the form of CNG or LNG and is
distributed under the brand name Redeem, has experienced rapid growth in recent years, increasing by 30.2% from 2018
to 2019. This demand for Redeem is attributable to the dramatic reduction in the amount of climate-harming greenhouse
gas that can be achieved through the use of Redeem RNG and pressure from politicians, regulators, non-governmental
organizations and the investment community directed at companies to reduce their contributions to climate change. To the
extent demand for RNG continues to increase, we expect our expanded supply agreement with BP, discussed under
“2018-2020 Developments” above, could increase our volume-related revenue due to increased volumes of RNG vehicle
fuel sold and increased generation of RINs and LCFS Credits. In addition, such an increase in RNG demand could also
result in more robust competition for supplies of RNG, including from other vehicle fuel providers, gas utilities (which
may have distinct advantages in accessing RNG supply, including potential use of ratepayer funds to fund RNG purchases
if approved by a utility’s regulatory commission) and other users and providers. We may invest in production projects to
help ensure that we have adequate supply of RNG.
RINs and LCFS Credits. When we sell RNG and conventional natural gas for use as a vehicle fuel, we are eligible to
generate RINs and LCFS Credits, which we then seek to sell to third parties.
The markets for RINs and LCFS Credits have been volatile and unpredictable in recent periods, and the prices for
these credits have been subject to significant fluctuations. For example, in 2019 market prices for RINs were as high as
approximately $1.90 and as low as approximately $0.50. Additionally, the value of RINs and LCFS Credits, and
consequently the revenue levels we may receive from our sale of these credits, may be adversely affected by changes to
the federal and state programs under which these credits are generated and sold. Further, our ability to generate revenue
from sales of these credits depends on our strict compliance with these federal and state programs, which are complex and
can involve a significant degree of judgment. If the agencies that administer and enforce these programs disagree with our
judgments, otherwise determine we are not in compliance, conduct reviews of our activities or make changes to the
programs, then our ability to generate or sell these credits could be temporarily restricted pending completion of reviews
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or as a penalty, permanently limited or lost entirely, and we could be subject to fines or other sanctions. Any of these
outcomes could force us to purchase credits in the open market to cover any credits we have contracted to sell, retire credits
we may have generated but not yet sold, reduce or eliminate a significant revenue stream or incur substantial additional
and unplanned expenses.
In addition, we recognized no revenue from sales of LCFS Credits during the third and fourth quarters of 2017 because
CARB had restricted our ability to sell and transfer LCFS Credits pending completion of an administrative review. We
were, however, required to settle preexisting contractual obligations to transfer LCFS Credits to third parties by making
cash payments totaling $7.0 million, the equivalent value of the LCFS Credits we would have otherwise transferred to
satisfy our obligations. In November 2017, CARB invalidated certain LCFS Credits we had generated in prior periods and
released the restriction on our ability to sell and transfer LCFS Credits.
Risk Management Activities
From time to time, we enter into natural gas fuel sales contracts that require us to sell CNG or LNG 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 the natural gas to our customers.
In an effort to mitigate the volatility of our earnings related to any futures contracts and to reduce our risk related to
our fixed price sales contracts, we operate under a natural gas hedging policy pursuant to which we 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 exposure to cash flow variability related to fixed price sales contracts entered into after the date of
the policy. Unless otherwise agreed in advance by our board of directors and the derivatives committee thereof, we will
conduct our futures contract activities and enter into fixed price sales contracts only in accordance with our natural gas
hedging policy.
Due to the restrictions of our hedging policy, we expect to offer few 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 contract.
In October 2018, in support of the our Zero Now truck financing program, we executed two commodity swap contracts
with Total Gas & Power North America, an affiliate of TOTAL and THUSA, for a total of five million diesel gallons
annually from April 1, 2019 to June 30, 2024. These commodity swap contracts are intended to manage risks related to
the diesel-to-natural gas price spread in connection with the natural gas fuel supply commitments we have made and expect
to make in our current and anticipated fueling agreements with fleet operators that participate in the Zero Now program.
Critical Accounting Policies
This discussion is based upon our consolidated financial statements included in this report, which have been prepared
in accordance with accounting principles generally accepted in the United States of America (“US GAAP”). The
preparation of consolidated financial statements in conformity with US GAAP requires management to make estimates
and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual
results could differ from those estimates and may result in material effects on our operating results and financial position.
We believe the critical accounting policies discussed below affect our more significant estimates made in preparing
our consolidated financial statements. See Notes 1 and 2 for more information about these and our other significant
accounting policies.
Revenue Recognition
In general, revenue is recognized when control of the promised goods or services is transferred to our customers, in
an amount that reflects the consideration to which we expect to be entitled in exchange for the goods or services. To
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achieve that core principle, a five-step approach is applied: (1) identify the contract with a customer, (2) identify the
performance obligations in the contract, (3) determine the transaction price, (4) allocate the transaction price to the
performance obligations in the contract, and (5) recognize revenue allocated to each performance obligation when we
satisfy the performance obligation. A performance obligation is a promise in a contract to transfer a distinct good or service
to the customer, and is the unit of account for revenue recognition.
We recognize revenue on various products and services.
Our volume-related revenue primarily consists of sales of RNG, CNG and LNG fuel, O&M services, and RINs and
LCFS Credits in addition to changes in fair value of our derivative instruments.
Fuel and O&M services are sold pursuant to contractual commitments over defined goods-and-service delivery
periods. These contracts typically include a stand-ready obligation to supply natural gas and/or provide O&M services
daily based on a committed and agreed upon routine maintenance schedule or when and if called upon by the customer.
We recognize fuel and O&M services revenue in the amount to which we have the right to invoice. We have a right
to consideration based on the amount of gasoline gallon equivalents of natural gas dispensed by the customer and current
pricing conditions, which are typically billed to the customer on a monthly basis. Since payment terms are less than a year,
we have elected the practical expedient which allows us to not assess whether a customer contract has a significant
financing component.
We sell RIN Credits and LCFS Credits to third parties that need the credits to comply with federal and state
requirements. Revenue is recognized on these credits when there is an agreement in place to monetize the credits at a
determinable price.
Changes in fair value of derivative instruments relates to our commodity swap and customer fueling contracts. The
contracts are measured at fair value with changes in the fair value recorded in our consolidated statements of operations
in the period incurred. The amounts are classified as revenue because our commodity swap contracts are used to
economically offset the risk associated with the diesel-to-natural gas price spread resulting from anticipated customer
fueling contracts under our Zero Now truck financing program.
Station construction contracts are generally short-term, except for certain larger and more complex stations, which
can take up to 24 months to complete. For most of our station construction contracts, the customer contracts with us to
provide a significant service of integrating a complex set of tasks and components into a single station. Hence, the entire
contract is accounted for as one performance obligation.
We recognize revenue over time as we perform under our station construction contracts because of the continual
transfer of control of the goods to the customer, who typically controls the work in process. Revenue is recognized based
on the extent of progress towards completion of the performance obligation and is recorded proportionally as costs are
incurred. Costs to fulfill our obligations under these contracts typically include labor, materials and subcontractors’ costs,
other direct costs and an allocation of indirect costs.
Refinements of estimates to account for changing conditions and new developments are continuous and characteristic
of the process. Many factors that can affect contract profitability may change during the performance period of the contract,
including differing site conditions, the availability of skilled contract labor, the performance of major suppliers and
subcontractors, and unexpected changes in material costs. Because a significant change in one or more of these estimates
could affect the profitability of these contracts, the contract price and cost estimates are reviewed periodically as work
progresses and adjustments proportionate to the cost-to-cost measure of progress are reflected in contract revenues in the
reporting period when such estimates are revised as discussed above. Provisions for estimated losses on uncompleted
contracts are recorded in the period in which the losses become known.
In certain contracts with our customers, we agree to provide multiple goods or services, including construction of and
sale of a station, O&M services, and sale of fuel to the customer. These contracts have multiple performance obligations
because the promise to transfer each separate good or service is separately identifiable and is distinct. This evaluation
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requires significant judgment and the decision to combine a group of contracts or separate the combined or single contract
into multiple performance obligations could change the amount of revenue recognized in one or more periods.
We allocate the contract price to each performance obligation using best estimates of the standalone selling price of
each distinct good or service in the contract. The primary method used to estimate the standalone selling price for fuel and
O&M services is observable standalone sales, and the primary method used to estimate the standalone selling price for
station construction sales is the expected cost plus a margin approach because we sell customized customer-specific
solutions. Under this approach, we forecast expected costs of satisfying a performance obligation and then add an
appropriate margin for the good or service.
AFTC is considered variable consideration because it can either increase or decrease the transaction price based on
volumes of vehicle fuel sold. Additionally, AFTC is not recognized as revenue until it is authorized through federal
legislation, which also provides a determinable price. We recognize revenue in the period the credit is authorized through
federal legislation.
We collect and remit taxes assessed by various governmental authorities that are imposed on and concurrent with
revenue-producing transactions between us and our customers. These taxes may include, among others, fuel, sales and
value-added taxes. We report the collection of these taxes on a net basis and they are excluded from revenue and cost of
goods sold.
Impairment of Goodwill and Long-Lived Assets
Goodwill represents the excess of costs incurred over the fair value of the net assets of acquired businesses. We assess
our goodwill using either a qualitative or quantitative approach to determine whether it is more likely than not that the fair
value of our reporting unit is less than its carrying value. We are required to use judgment when applying the goodwill
impairment test, including, among other considerations, the identification of reporting unit(s), the assessment of qualitative
factors, and the estimation of fair value of a reporting unit in the quantitative approach. We determined that we are a single
reporting unit for the purpose of goodwill impairment tests. We perform the impairment test annually on October 1, or
more frequently if facts or circumstances change that would indicate that the carrying amount may be impaired.
The qualitative goodwill assessment includes the potential effect on a reporting unit’s fair value of certain events and
circumstances, including its enterprise value, macroeconomic conditions, industry and market considerations, cost factors,
and other relevant entity-specific events. If it is determined, based upon the qualitative assessment, that it is more likely
than not that the reporting unit’s fair value is less than its carrying amount, then a quantitative impairment test is performed.
Alternatively, we may bypass the qualitative assessment for a reporting unit and directly perform the quantitative
assessment.
The quantitative assessment estimates the reporting unit's fair value based on its market capitalization plus an assumed
control premium as evidence of fair value. The estimates used to determine the fair value of the reporting unit may change
based on results of operations, macroeconomic conditions stock price fluctuations or other factors. Changes in these
estimates could materially affect our assessment of the fair value and goodwill impairment for the reporting unit.
For our most recent goodwill impairment test, which was our annual test performed on October 1, 2019, we performed
a quantitative impairment assessment for the reporting unit as described above. In this test, the fair value of the reporting
unit exceeded its carrying value by 9%.
We evaluated the volatility in the market price of our common stock subsequent to our annual test date through
December 31, 2019, and considered whether there were any other events or circumstances that would more likely than not
reduce the fair value of our reporting unit below its carrying value on a sustained basis, and concluded it was not more
likely than not that the fair value of our reporting unit decreased below its carrying value, on a sustained basis. As a result,
an interim impairment test was not considered necessary during the three months ended December 31, 2019.
If a decline in the market price of our common stock and our market capitalization were sustained, or if other events
or circumstances change that would more likely than not reduce the fair value of our reporting unit below its carrying
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value, on a sustained basis, then we may perform impairment tests more frequently and it is possible that our goodwill
could become impaired, which could result in a material charge and adversely affect our results of operations.
We review the carrying value of our long-lived assets, including property and equipment and intangible assets with
finite useful lives, for impairment whenever events or changes in circumstances indicate that the carrying value of an asset
or asset group may not be recoverable. Events that could result in an impairment review include, among others, a significant
decrease in the operating performance of a long-lived asset or asset group or the decision to close a fueling station.
Impairment testing involves a comparison of the sum of the undiscounted future cash flows of the asset or asset group to
its carrying amount. If the sum of the undiscounted future cash flows exceeds the carrying amount, then no impairment
exists. If the carrying amount exceeds the sum of the undiscounted future cash flows, then a second step is performed to
determine the amount of impairment, if any, to be recognized. An impairment loss is recognized to the extent that the
carrying amount of the asset or asset group exceeds its fair value. The fair value of the asset or asset group is based on
estimated discounted future cash flows of the asset or asset group using a discount rate commensurate with the related risk.
The estimate of future cash flows requires management to make assumptions and to apply judgment, including forecasting
future sales and expenses and estimating useful lives of the assets. These estimates can be affected by a number of factors,
including, among others, future results, demand and economic conditions, many of which can be difficult to predict.
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 carrying amounts of existing 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. Valuation allowances are established when management
determines it is more likely than not that deferred tax 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 US GAAP income and the
amounts and estimated timing of the reversal of any deferred tax assets and liabilities.
We have 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% likelihood of being realized
upon ultimate settlement. We recognize potential accrued interest and penalties related to unrecognized tax benefit in
income tax expense.
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 to resolve. Although we believe
that adequate consideration has been given to these issues, it is possible that the ultimate resolution of these issues could
be significantly different than originally estimated.
Fair Value Measurements
We have established a framework that follows the authoritative guidance for fair value measurements with respect to
assets and liabilities that are measured at fair value on a recurring basis and non-recurring basis. Under the framework,
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 framework 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 and are developed based on market data obtained from sources
independent of our Company. Unobservable inputs are inputs that reflect our assumptions about the factors market
participants would use in valuing the asset or liability and are 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
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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 the valuation of assets disposed and liabilities extinguished
related to business divestitures and impairment of long-lived assets, as well as the valuation of commodity swaps and
customer contracts, and warrants, all of which requires significant judgment.
Recently Adopted Accounting Changes and Recently Issued and Adopted Accounting Standards.
See Note 1 for information about recently adopted accounting changes and recently issued accounting standards.
Results of Operations
The discussions below compare our results of operations in 2019 and 2018. Historical results are not indicative of the
results to be expected in the current period or any future period.
2019 Compared to 2018
The table below presents, for each period, each line item of our statement of operations data as a percentage of our
total revenue for the period. The narrative that follows provides a comparative discussion of certain of these line items
between periods.
Statement of Operations Data:
Revenue:
Product revenue
Service revenue
Total revenue
Operating expenses:
Cost of sales (exclusive of depreciation and amortization shown separately below):
Product cost of sales
Service cost of sales
Change in fair value of derivative warrants
Selling, general and administrative
Depreciation and amortization
Total operating expenses
Operating income (loss)
Interest expense
Interest income
Other income (expense), net
Loss from equity method investments
Gain from sale of certain assets of subsidiary
Loss from formation of equity method investment
Income (loss) before income taxes
Income tax benefit (expense)
Net income (loss)
Loss from noncontrolling interest
Net income (loss) attributable to Clean Energy Fuels Corp.
Year Ended December 31,
2018
2019
88.9 %
11.1
100.0
86.7 %
13.3
100.0
56.1
5.3
0.2
22.3
15.0
98.9
1.1
(4.6)
0.8
(0.2)
(0.8)
1.4
(0.3)
(2.6)
(0.1)
(2.7)
1.6
(1.1)%
53.9
7.7
(0.3)
21.3
14.4
97.0
2.9
(2.2)
0.7
0.6
—
2.2
—
4.2
(0.2)
4.0
2.1
6.1 %
Revenue. Revenue decreased by $2.4 million to $344.1 million for 2019, from $346.4 million for 2018. This
decrease was primarily due to the unfavorable change in fair value of our commodity swap and customer contracts entered
into in connection with our Zero Now truck financing program, lower station construction sales and lower revenue from
44
the sale of used trucks, partially offset by an increase in AFTC revenue, as well as an increase in revenue from higher
volumes.
Volume-related revenue, excluding the impact of the change in fair value of our commodity swap and customer
contracts entered into in connection with our Zero Now truck financing program, increased by $3.8 million between
periods, attributable to an increase in gallons of CNG and LNG delivered, and increased revenue from RINs and LCFS
Credits. The impact to volume-related revenue as a result of the change in fair value of our commodity swap and customer
contracts entered into in connection with our Zero Now truck financing program was $(16.9) million, as we recognized an
unrealized gain of $10.3 million in 2018 compared to an unrealized loss of $(6.6) million in 2019 (see Note 8 for more
information).
Our effective price per gallon charged decreased by $0.06 per gallon to $0.70 per gallon in 2019 compared to $0.76
in 2018, excluding the effect of the change in fair value of derivative instruments discussed above. Our effective price per
gallon is defined as revenue generated from selling RNG, CNG, LNG and any related RINs and LCFS Credits and
providing O&M services to our vehicle fleet customers at stations we do not own and for which we receive a per-gallon
or fixed fee, all divided by the total GGEs delivered less GGEs delivered by non-consolidated entities, such as entities that
are accounted for under the equity method.
Station construction sales decreased by $2.4 million between periods, due to fewer construction projects.
AFTC revenue increased by $20.4 million between periods due to our recognition in 2019 of AFTC revenue for the
vehicle fuel we sold in 2018 and 2019. In 2018, we recognized AFTC revenue for the vehicle fuel we sold in 2017.
Cost of sales. Cost of sales decreased by $0.8 million to $212.1 million in 2019, from $212.9 million in 2018. This
decrease was primarily due to a $1.6 million decrease in station construction costs due to fewer construction projects, and
a $7.6 million decrease in costs to purchase used heavy-duty trucks that we sold to our customers. These decreases were
partially offset by an $8.8 million increase in gas commodity costs due to the increase in gallons delivered during 2019
partially offset by a lower average cost per gallon in 2019 compared to 2018.
Our effective cost per gallon decreased by $0.02 per gallon to $0.47 per gallon in 2019 compared to $0.49 per gallon
in 2018. Our effective cost per gallon is defined as the total costs associated with delivering natural gas, including gas
commodity costs, transportation fees, liquefaction charges, and other site operating costs, plus the total cost of providing
O&M services at stations that we do not own and for which we receive a per-gallon or fixed fee, including direct technician
labor, indirect supervisor and management labor, repair parts and other direct maintenance costs, all divided by the total
GGEs delivered less GGEs delivered by non-consolidated entities, such as entities that are accounted for under the equity
method. The decrease in our effective cost per gallon was due to decreases in natural gas prices and transportation costs.
Change in fair value of derivative warrants. Change in fair value of derivative warrants, all of which were issued by
our subsidiary, NG Advantage, changed from an expense of $0.5 million in 2018, to income of $1.0 million in 2019 due
to a change in the estimated fair value.
Selling, general and administrative. Selling, general and administrative expenses decreased by $3.8 million to $73.4
million for 2019, from $77.2 million for 2018. This decrease was primarily driven by continued cost reduction efforts.
Depreciation and amortization. Depreciation and amortization decreased by $2.2 million to $49.6 million in 2019,
from $51.9 million in 2018, primarily due to a lower amount of depreciable assets.
Interest expense. Interest expense decreased by $8.4 million to $7.6 million in 2019, from $15.9 million in 2018.
This decrease was primarily due to a reduction of outstanding indebtedness between periods.
Other income (expense), net. Other income (expense), net, changed from an expense of $0.6 million in 2018 to
income of $2.0 million in 2019, primarily due to gains recorded from disposal of certain assets.
45
Loss from equity method investments. Loss from equity method investments decreased by $2.6 million between
periods, which was primarily attributable to improved operating results from SAFE&CEC S.r.l.
Gain from sale of certain assets of subsidiary. In 2019, we recorded a gain of $7.5 million as a result of the satisfaction
of certain performance criteria related to the assets sold in the BP Transaction and an amendment to the related Asset
Purchase Agreement. In 2018, we recorded a gain of $4.8 million as a result of the satisfaction of certain performance
criteria related to the assets sold in the BP Transaction. See Note 4 for more information.
Loss from formation of equity method investment. In 2018, we recorded a loss of $1.2 million related to costs incurred
in satisfaction of commitments made in connection with the CEC Combination. There was no comparable loss in 2019.
Income tax expense. Income tax expense increased between periods, primarily due an increase in deferred taxes
associated with goodwill which were partially offset by a reduction in the Company’s expected state tax expense.
Loss attributable to noncontrolling interest. In 2019, we recorded a $7.2 million loss for the noncontrolling interest
in the net loss of NG Advantage, compared to a $5.4 million loss for 2018. The noncontrolling interest in NG Advantage
represents a 37.0% and 35.4% minority interest that was held by third parties during 2018 and 2019, respectively.
Seasonality and Inflation
To some extent, we experience seasonality in our results of operations. Some of our customers tend to consume more
natural gas vehicle fuel in the 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.
Historically, inflation has not significantly affected our operating results; however, costs for construction, repairs,
maintenance, electricity and insurance are all subject to inflationary pressures, which could affect our ability to maintain
our stations adequately, build new stations, expand our existing facilities or pursue additional facilities, and could
materially impact our operating costs.
Liquidity and Capital Resources
Liquidity
Liquidity is the ability to meet present and future financial obligations through operating cash flows, the sale or
maturity of investments or the acquisition of additional funds through capital management. Our financial position and
liquidity are, and will continue to be, influenced by a variety of factors, including the level of our outstanding indebtedness
and the principal and interest we are obligated to pay on our indebtedness, which could be influenced by the potential
discontinuance of LIBOR for certain of our debt instruments that tie interest rates to this metric; the amount and timing of
any additional debt or equity financing we may pursue; determinations to buy-out future commitments; our capital
expenditure requirements; any merger, divestiture or acquisition activity; and our ability to generate cash flows from our
operations. We expect cash provided by our operating activities to fluctuate as a result of a number of factors, including
our operating results and the factors that affect these results, including the amount and timing of our natural gas vehicle
fuel sales, station construction sales, sales of RINs and LCFS Credits and recognition of government credits, grants and
incentives, if any; fluctuations in commodity, station construction and labor costs and natural gas, RIN and LCFS Credit
prices; variations in the fair value of certain of our derivative instruments that are recorded in revenue; and the amount and
timing of our billing, collections and liability payments, as discussed under “Key Trends-Our Performance” above.
Cash Flows
Operating Activities. Cash provided by operating activities was $12.3 million in 2019, compared to $38.0 million in
2018. The decrease in cash provided by operating activities was primarily attributable to the AFTC revenue collected
in 2018 and changes in working capital resulting from the timing of receipts and payments of cash.
46
Investing Activities. Cash used in investing activities was $1.5 million in 2019, compared to cash provided by investing
activities of $54.4 million in 2018. The decrease in cash provided by investing activities was attributable to a decrease in
maturities and sales of short-term investments in 2019, partially offset by an increase in proceeds from property and
equipment disposals and an increase in earn-out proceeds received in connection with the BP Transaction. The decrease
in cash provided by investing activities in 2019 was also attributable to an increase in purchases of property and equipment
between periods.
Financing Activities. Cash provided by financing activities was $7.7 million in 2019, compared to cash used in
financing activities of $95.2 million in 2018. Cash provided by financing activities in 2019 was primarily attributable to
proceeds from debt instruments and finance lease obligations, partially offset by repayments of debt instruments and
finance lease obligations. Cash used in financing activities in 2018 consisted primarily of our repayment of debt
instruments and finance lease obligations, partially offset by cash proceeds, net of fees, from our issuance of stock in the
Total Private Placement.
Capital Expenditures, Indebtedness and Other Uses of Cash
We require cash to fund our capital expenditures, operating expenses and working capital and other requirements,
including costs associated with fuel sales; outlays for the design and construction of new fueling stations; additions or
other modifications to existing fueling stations; debt repayments and repurchases; investments in RNG production;
maintenance of LNG production facilities; supporting our operations, including maintenance and improvements of our
infrastructure; supporting our sales and marketing activities, including support of legislative and regulatory initiatives;
financing natural gas vehicles for our customers; any investments in other entities; any mergers or acquisitions; pursuing
market expansion as opportunities arise, including geographically and to new customer markets; and to fund other activities
or pursuits and for other general corporate purposes.
Our business plan calls for approximately $18.0 million in capital expenditures in 2020. These capital expenditures
primarily relate to the construction of CNG fueling stations, IT software and equipment and LNG plant maintenance costs
and we expect to fund these expenditures primarily through cash on hand and cash generated from operations.
In addition, NG Advantage may spend as much as $12.8 million to purchase additional equipment in support of its
operations and customer contracts or buy-out future commitments, among other things.
We had total indebtedness, consisting of our debt and finance leases, of approximately $92.4 million in principal
amount as of December 31, 2019, of which approximately $56.7 million, $6.9 million, $7.0 million, $11.9 million, $9.6
million and $0.3 million is expected to become due in 2020, 2021, 2022, 2023, 2024 and thereafter, respectively. Based
on outstanding debt balances and applicable interest rates at December 31, 2019, we expect our total interest payment
obligations relating to our indebtedness to be approximately $4.8 million for the year ending December 31, 2020. In
addition, in connection with implementing our Zero Now truck financing program, we have entered into agreements that
permit us to incur a material amount of additional debt on a delayed draw basis and obligate us to make interest and other
fee payments that vary in amount based on the outstanding principal of this debt and certain other factors; none of this
potential debt nor the related interest and other payments are included in the foregoing estimates other than the principal
amount of $4.4 million drawn as of December 31, 2019. Although we believe we have sufficient liquidity and capital
resources to repay our debt coming due in the next 12 months, we may elect to pursue alternatives, such as refinancing or
debt or equity offerings, to increase our cash management flexibility. As of December 31, 2019, we have $50.0 million of
outstanding 7.5% convertible notes outstanding, which mature in June 2020. We are permitted to issue up to 14.0 million
shares of common stock to repay a portion of the principal amount of these outstanding convertible notes.
We intend to make payments under our various debt instruments when due and pursue opportunities for earlier
repayment and/or refinancing if and when these opportunities arise.
Sources of Cash
Historically, our principal sources of liquidity have consisted of cash on hand, cash provided by our operations,
including, if available, AFTC and other government credits, grants and incentives, cash provided by financing activities,
47
and sales of assets. As of December 31, 2019, we had total cash and cash equivalents and short-term investments of $106.1
million, compared to $95.5 million as of December 31, 2018.
We expect cash provided by our operating activities to fluctuate depending on our operating results, which can be
affected by the factors described above, as well as the other factors described in this MD&A and “Item 1A. Risk Factors”
of this report.
In October 2018 and January 2019, we entered into agreements to implement our Zero Now truck financing program,
which permit us to incur up to an additional $100.0 million of indebtedness through the beginning of January 2022,
obligate us to make certain interest and other fee payments in connection with this debt and THUSA’s related guaranty
(which payments will vary in amount but will be owed by us regardless of the revenue we may receive from the program),
and subject us to potential additional payments in connection with related commodity swap arrangements. We are
permitted to use any proceeds we receive under these agreements solely to fund the incremental cost of trucks purchased
or financed by operators that participate in the Zero Now program. See “Recent Developments” and “Key Trends” above
and Note 13 of this report for more information.
We believe our cash and cash equivalents and short-term investments and anticipated cash provided by our operating
and financing activities will satisfy our business requirements for at least the 12 months following the date of this report.
Subsequent to that period, we may need to raise additional capital to fund any planned or unanticipated capital
expenditures, investments, debt repayments or other expenses that we cannot fund through cash on-hand, cash provided
by our operations or other sources. Moreover, we may use our cash resources faster than we predict due to unexpected
expenditures or higher-than-expected expenses, in which case we may need to seek capital from alternative sources sooner
than we anticipate.
The timing and necessity of any future capital raise would depend on various factors, including our rate and volume
of, and prices for, natural gas sales and other volume-related activity, new station construction, debt repayments (either
before or at maturity) and any potential mergers, acquisitions, investments, divestitures or other strategic relationships we
may pursue, as well as the other factors that affect our revenue and expense levels as described in this MD&A and
elsewhere in this report.
We may seek to raise additional capital through one or more sources, including, among others, selling assets, obtaining
new or restructuring existing debt, obtaining equity capital, or any combination of these or other potential sources of
capital. We may not be able to raise capital when needed, on terms that are favorable to us or our stockholders or at all.
Any inability to raise necessary capital may impair our ability to develop and maintain natural gas fueling infrastructure,
invest in strategic transactions or acquisitions or repay our outstanding indebtedness and may reduce our ability to support
and build our business and generate sustained or increased revenue.
Contractual Obligations
The table below represents the scheduled maturities of our contractual obligations as of December 31, 2019. This
table excludes certain potential contractual obligations because they may involve future cash payments that are considered
uncertain and cannot be estimated because they vary based upon future conditions; however, the exclusion of these
48
obligations should not be construed as an implication that they are immaterial, as they could significantly affect our short-
and long-term liquidity and capital resource needs depending on a variety of future events, facts and conditions.
Payments Due by Period
Contractual Obligations: (in thousands)
Long-term debt (a)
Finance lease obligations (b)
Operating lease commitments (c)
Long-term take-or-pay contracts (d)
Long-term supply contract (e)
Construction contracts (f)
Total
$
1 - 3 years 3 - 5 years
Total
99,807 $
3,808
46,502
9,649
28,736
5,092
Less than
1 year
60,727 $
767
5,484
5,769
5,076
5,092
82,915 $
More than
17,324 $
21,756 $
1,239
8,394
2,655
23,660
—
53,272 $
1,488
7,416
1,225
—
—
31,885 $
5 years
—
314
25,208
—
—
—
25,522
$ 193,594 $
(a) Consists of long-term debt to finance acquisitions and equipment purchases, including future interest payments. For our variable-rate debt
(the SG Facility as defined in Note 13), we have assumed an interest rate of 3.1% (LIBOR plus 1.30%) as of December 31, 2019.
(b) Consists of finance lease obligations to finance equipment purchases, including future interest payments.
(c) Consists of various space and ground leases for our Boron Plant, office spaces and fueling stations as well as leases for equipment.
(d) Represents our estimates for long-term natural gas purchase contracts with a take-or-pay commitment.
(e) Represents our estimates for one long-term natural gas supply contract for our subsidiary NG Advantage, which entered into an arrangement
with BP for the supply, sale and transportation of CNG through March 2022.
(f) Consists of our obligations to fund various fueling station construction projects, net of amounts funded through December 31, 2019 and
excluding contractual commitments related to station sales contracts.
Off-Balance Sheet Arrangements
As of December 31, 2019, we had the following off-balance sheet arrangements that have had, or are reasonably likely
to have, a material current or future effect on our financial condition, changes in financial condition, revenue or expenses,
results of operations, liquidity, capital expenditures or capital resources:
• Outstanding surety bonds for construction contracts and general corporate purposes totaling $29.9 million;
• Two long-term natural gas purchase contract with a take-or-pay commitment, the amount of which is shown
under “Contractual Obligations” above;
• Quarterly fixed price natural gas purchase contracts with take-or-pay commitments, the amount of which is shown
under “Contractual Obligations” above;
• One long-term natural gas sale contract with a fixed supply commitment, the amount of which is shown under
“Contractual Obligations” above, along with a guaranty agreement; and
• One long-term natural gas sale contract with a fixed supply commitment.
We provide surety bonds primarily for construction contracts in the ordinary course of our business, as a form of
guarantee. No liability has been recorded in connection with our surety bonds because, based on historical experience and
available information, we do not believe it is probable that any amounts will be required to be paid under these
arrangements for which we will not be reimbursed.
As of December 31, 2019, we had two long-term natural gas purchase contracts with a take-or-pay commitment,
which require us to purchase minimum volumes of natural gas at index-based prices and expire in December 2020 and
49
June 2022, respectively. Additionally, as of December 31, 2019, we had quarterly fixed-price natural gas purchase
contracts with take-or-pay commitments extending through June 2023.
NG Advantage has entered into an arrangement with BP for the supply, sale and reservation of a specified volume of
CNG transportation capacity until March 2022. In connection with the arrangement, on February 28, 2018, we entered
into a guaranty agreement with NG Advantage and BP in which we guarantee NG Advantage’s payment obligations to
the customer in the event of a default by NG Advantage under the supply arrangement, in an amount up to $30.0 million
plus related fees. Our guaranty is in effect until thirty days following our notice to BP of termination.
In addition, as of December 31, 2019, we had a fixed supply arrangement with UPS for the supply and sale of 170.0
million GGEs of RNG through March 2026.
Item 7A. Quantitative and Qualitative Disclosures about Market Risk.
In the ordinary course of our business, we are exposed to various market risks, including commodity price risks, risks
related to foreign currency exchange rates, and risks related to fluctuations in interest rates.
Commodity Price Risk
We are subject to market risk with respect to our sales of natural gas, which have historically been subject to volatile
market conditions. Our exposure to market risk is heightened when we have a fixed-price sales contract with a customer
that is not covered by a futures contract, or when we are otherwise unable to pass through natural gas price increases to
customers. Natural gas prices and availability are affected by many factors, including, among others, drilling activity,
supply, weather conditions, overall economic conditions and foreign and domestic government regulations.
Natural gas costs represented $83.3 million, $94.9 million and $94.0 million of our cost of sales in 2017, 2018 and
2019, respectively.
In October 2018, in support of our Zero Now truck financing program, we entered into two commodity swap contracts
with Total Gas & Power North America, an affiliate of TOTAL and THUSA, for a total of five million diesel gallons
annually from April 1, 2019 to June 30, 2024. These commodity swap contracts are intended to manage risks related to
the diesel-to-natural gas price spread in connection with the natural gas fuel supply commitments we expect to make in
our anticipated fueling agreements with fleet operators that participate in the Zero Now truck financing program.
We have prepared a sensitivity analysis to estimate our exposure to price risk with respect to our commodity swap
contracts. If the diesel-to-natural gas price spread were to fluctuate by 10% as of December 31, 2019, we would expect a
corresponding fluctuation in the fair value of our commodity swap contracts of approximately $5.8 million.
Foreign Currency Exchange Rate Risk
Before completion of the CEC Combination on December 29, 2017, we had foreign operations that exposed us to
foreign currency exchange gains and losses. Since the functional currency of those foreign subsidiaries is their local
currency, the currency effects of translating the financial statements of the foreign subsidiaries, which operate in local
currency environments, are included in the accumulated other comprehensive loss component of consolidated equity in
our consolidated financial statements and do not impact earnings.
Foreign currency transaction gains and losses not in these subsidiaries’ functional currency, however, do impact
earnings, but these amounts were not material for 2018 and 2019. For the years ended December 31, 2018 and 2019, our
primary exposure to foreign currency exchange rates related to our other Canadian operations that had certain outstanding
accounts receivable and accounts payable denominated in the U.S. dollar, which were not hedged.
We have prepared a sensitivity analysis to estimate our exposure to market risk with respect to our monetary
transactions denominated in a foreign currency. If the exchange rates on these assets and liabilities were to fluctuate by
50
10% from the rates as of December 31, 2019, we would expect a corresponding fluctuation in the value of the assets and
liabilities of approximately $0.3 million.
Interest Rate Risk
As of December 31, 2019, we had $4.4 million of debt that bears interest at a rate equal to LIBOR plus 1.30% per
annum. Thus, our interest expense would fluctuate with a change in LIBOR. If LIBOR were to increase or decrease by 1%
for the year, our annual interest expense would increase or decrease by approximately $44,000.
The term credit agreement with SG permits the Company to draw loans from time to time through the beginning of
January 2022. These loans are subject to an interest rate indexed to LIBOR which is expected to be discontinued after
2021. We intend to monitor the developments with respect to the potential discontinuance of LIBOR after 2021 and work
with our lenders under the credit agreement, including SG, and any other indebtedness with an interest rate tied to LIBOR
to minimize the effect of such a discontinuance on our financial condition and results of operations; however, the effect of
the anticipated discontinuance of LIBOR on us and our debt instruments remains uncertain. If our lenders have increased
costs due to changes in LIBOR, we may experience potential increases in interest rates on our variable rate debt, which
could adversely impact our interest expense, results of operations and cash flows.
Item 8. Financial Statements and Supplementary Data.
The following tables set forth our quarterly consolidated statements of operations data for the eight quarters ended
December 31, 2019. The information for each quarter is unaudited and we have prepared the information on the same basis
as the audited consolidated financial statements included in this report. This information includes all adjustments that
management considers necessary for the fair presentation of such data, which include only normal recurring adjustments.
See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations of this report for
descriptions of the effects of any unusual or infrequently occurring items recognized in any of the periods covered by the
below quarterly data. The quarterly data should be read together with our consolidated financial statements and related
51
notes included in this report. The results of operations for any one quarter are not necessarily indicative of results to be
expected in the current period or any future period.
Revenue:
Product revenue
Service revenue
Total revenue
Operating expenses:
(In thousands, except per share data, Unaudited)
Three Months Ended
March 31,
2018
June 30,
2018
September 30, December 31,
2018
2018
$ 92,251 $ 61,120 $
10,152
102,403
9,347
70,467
67,441 $
9,879
77,320
87,027
9,202
96,229
Cost of sales (exclusive of depreciation and amortization
shown separately below):
Product cost of sales
Service cost of sales
Change in fair value of derivative warrants
Selling, general and administrative
Depreciation and amortization
Total operating expenses
Operating income (loss)
Interest expense
Interest income
Other income (expense), net
Income (loss) from equity method investments
Gain from sale of certain assets of subsidiary
Loss from formation of equity method investment
Income (loss) before income taxes
Income tax expense
Net income (loss)
Loss attributable to noncontrolling interest
Net income (loss) attributable to Clean Energy Fuels Corp.
Basic income (loss) per share
Diluted income (loss) per share
50,199
4,597
(21)
18,858
12,801
86,434
15,969
(4,503)
575
(12)
(1,468)
—
—
10,561
(88)
10,473
1,749
41,396
4,255
(71)
19,939
13,332
78,851
(8,384)
(4,527)
489
79
(729)
—
—
(13,072)
(89)
(13,161)
1,186
$ 12,222 $ (11,975) $
(0.07) $
$
(0.07) $
$
0.08 $
0.08 $
48,063
4,743
(9)
18,405
13,363
84,565
(7,245)
(4,096)
1,129
(193)
(542)
—
(1,163)
(12,110)
(89)
(12,199)
1,300
(10,899) $
(0.05) $
(0.05) $
54,851
4,820
644
20,005
12,354
92,674
3,555
(2,798)
664
(440)
16
4,782
—
5,779
(75)
5,704
1,158
6,862
0.03
0.03
52
Revenue:
Product revenue
Service revenue
Total revenue
Operating expenses:
Cost of sales (exclusive of depreciation and amortization shown
separately below):
Product cost of sales
Service cost of sales
Change in fair value of derivative warrants
Selling, general and administrative
Depreciation and amortization
Total operating expenses
Operating income (loss)
Interest expense
Interest income
Other income (expense), net
Income (loss) from equity method investments
Gain from sale of certain assets of subsidiary
Income (loss) before income taxes
Income tax expense
Net income (loss)
Loss attributable to noncontrolling interest
Net income (loss) attributable to Clean Energy Fuels Corp.
Basic income (loss) per share
Diluted income (loss) per share
Three Months Ended
March 31,
2019
June 30,
September 30, December 31,
2019
2019
2019
$ 68,448 $ 59,691 $
9,250
77,698
12,627
72,318
62,808 $ 107,522
12,093
11,626
119,615
74,434
54,430
4,398
1,614
18,434
12,479
91,355
(13,657)
(1,891)
580
2,670
(467)
—
(12,765)
(60)
(12,825)
1,879
40,121
7,489
(17)
17,933
12,605
78,131
(5,813)
(1,842)
567
93
(33)
—
(7,028)
(66)
(7,094)
1,711
$ (10,946) $ (5,383) $
(0.05) $ (0.03) $
$
(0.05) $ (0.03) $
$
43,145
6,787
(10)
17,640
12,247
79,809
(5,375)
(1,704)
560
165
377
—
(5,977)
(68)
(6,045)
1,711
(4,334) $
(0.02) $
(0.02) $
47,861
7,876
(2,626)
19,437
12,294
84,842
34,773
(2,137)
730
(938)
4
7,455
39,887
(664)
39,223
1,861
41,084
0.20
0.20
53
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
Consolidated Financial Statements
Report of Independent Registered Public Accounting Firm
Consolidated Balance Sheets
Consolidated Statements of Operations
Consolidated Statements of Comprehensive Income (Loss)
Consolidated Statements of Stockholders’ Equity
Consolidated Statements of Cash Flows
Notes to Consolidated Financial Statements
Financial Statement Schedule
Schedule II—Valuation and Qualifying Accounts
Page
55
57
58
59
60
61
62
109
54
Report of Independent Registered Public Accounting Firm
To the Stockholders and Board of Directors
Clean Energy Fuels Corp.:
Opinions on the Consolidated Financial Statements and Internal Control Over Financial Reporting
We have audited the accompanying consolidated balance sheets of Clean Energy Fuels Corp. and subsidiaries (the
Company) as of December 31, 2019 and 2018, 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, 2019, and
the related notes and financial statement schedule II (collectively, the consolidated financial statements). We also have
audited the Company’s internal control over financial reporting as of December 31, 2019, based on criteria established in
Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway
Commission.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial
position of the Company as of December 31, 2019 and 2018, and the results of its operations and its cash flows for each
of the years in the three-year period ended December 31, 2019, in conformity with U.S. generally accepted accounting
principles. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial
reporting as of December 31, 2019 based on criteria established in Internal Control – Integrated Framework (2013) issued
by the Committee of Sponsoring Organizations of the Treadway Commission.
Change in Accounting Principle
As discussed in Note 17 to the consolidated financial statements, the Company has changed its method of accounting for
leases as of January 1, 2019 due to the adoption of Financial Accounting Standards Board’s Accounting Standards
Codification (ASC) Topic 842, Leases.
Basis for Opinions
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 the Company’s consolidated financial statements and an opinion on the Company’s internal
control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company
Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company
in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange
Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and
perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material
misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained
in all material respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material
misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that
respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and
disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used
and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial
statements. 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.
55
Definition and Limitations of Internal Control Over Financial Reporting
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.
/s/ KPMG LLP
We have served as the Company’s auditor since 2001.
Irvine, California
March 10, 2020
56
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(In thousands, except share and per share data)
Current assets:
Assets
Cash, cash equivalents and current portion of restricted cash
Short-term investments
Accounts receivable, net of allowance for doubtful accounts of $1,919 and $2,412 as of December 31, 2018
and 2019, respectively
Other receivables
Inventory
Prepaid expenses and other current assets
Derivative assets, related party
Total current assets
Operating lease right-of-use assets
Land, property and equipment, net
Long-term portion of restricted cash
Notes receivable and other long-term assets, net
Long-term portion of derivative assets, related party
Investments in other entities
Goodwill
Intangible assets, net
Total assets
Liabilities and Stockholders' Equity
Current liabilities:
Current portion of debt
Current portion of finance lease obligations
Current portion of operating lease obligations
Accounts payable
Accrued liabilities
Deferred revenue
Derivative liabilities, related party
Total current liabilities
Long-term portion of debt
Long-term portion of finance lease obligations
Long-term portion of operating lease obligations
Other long-term liabilities
Total liabilities
Commitments and contingencies (Note 16)
Stockholders’ equity:
December 31, December 31,
2018
2019
$
30,624 $
65,646
68,865
15,544
34,975
8,444
1,508
225,606
—
350,568
4,000
17,470
8,824
26,079
64,328
2,207
699,082 $
4,712 $
693
—
19,024
48,469
7,361
—
80,259
75,003
3,776
—
15,035
174,073
$
$
49,222
56,929
61,760
84,898
29,874
11,109
—
293,792
28,627
323,912
4,000
31,622
3,270
26,305
64,328
1,229
777,085
56,013
615
3,359
27,376
67,697
7,338
164
162,562
32,872
2,715
26,206
9,701
234,056
Preferred stock, $0.0001 par value. 1,000,000 shares authorized; no shares issued and outstanding
Common stock, $0.0001 par value. 304,000,000 shares authorized; 203,599,892 shares and 204,723,055
shares issued and outstanding as of December 31, 2018 and 2019, respectively
Additional paid-in capital
Accumulated deficit
Accumulated other comprehensive loss
Total Clean Energy Fuels Corp. stockholders’ equity
Noncontrolling interest in subsidiary
Total stockholders’ equity
Total liabilities and stockholders’ equity
—
—
20
1,198,769
(688,653)
(2,138)
507,998
17,011
525,009
699,082 $
20
1,203,186
(668,232)
(1,566)
533,408
9,621
543,029
777,085
$
See accompanying notes to consolidated financial statements.
57
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except share and per share data)
Revenue:
Product revenue
Service revenue
Total revenue
Operating expenses:
Cost of sales (exclusive of depreciation and amortization shown
separately below):
Product cost of sales
Service cost of sales
Inventory valuation provision
Change in fair value of derivative warrants
Selling, general and administrative
Depreciation and amortization
Asset impairments and other charges
Total operating expenses
Operating income (loss)
Interest expense
Interest income
Other income (expense), net
Loss from equity method investments
Gain from extinguishment of debt, net
Gain from sale of certain assets of subsidiary
Loss from formation of equity method investment
Income (loss) before income taxes
Income tax benefit (expense)
Net income (loss)
Loss attributable to noncontrolling interest
Net income (loss) attributable to Clean Energy Fuels Corp.
Income (loss) per share:
Basic
Diluted
Weighted-average common shares outstanding:
Basic
Diluted
2017
Year Ended December 31,
2018
2019
$
287,292 $
54,307
341,599
307,839 $
38,580
346,419
298,469
45,596
344,065
216,413
26,258
13,158
(46)
95,715
56,614
67,934
476,046
(134,447)
(17,751)
1,497
139
(131)
3,195
70,658
(6,465)
(83,305)
1,914
(81,391)
2,154
(79,237) $
194,509
18,415
—
543
77,207
51,850
—
342,524
3,895
(15,924)
2,857
(566)
(2,723)
—
4,782
(1,163)
(8,842)
(341)
(9,183)
5,393
(3,790) $
185,557
26,550
—
(1,039)
73,444
49,625
—
334,137
9,928
(7,574)
2,437
1,990
(119)
—
7,455
—
14,117
(858)
13,259
7,162
20,421
(0.53) $
(0.53) $
(0.02) $
(0.02) $
0.10
0.10
$
$
$
150,430,239
150,430,239
180,655,435
180,655,435
204,573,287
205,987,509
See accompanying notes to consolidated financial statements.
58
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE
INCOME (LOSS) (In thousands)
Year Ended Decem
Clean Energy Noncontrolling
Fuels Corp.
Interest
ber 31,
2017
Year Ended Decem
Clean Energy Noncontrolling
ber 31,
2018
Year Ended Decem
Clean Energy Noncontrolling
ber 31,
2019
Total
Fuels Corp.
Interest
Total
Fuels Corp.
Interest
Total
Net income (loss)
Other comprehensive income (loss), net of tax:
Foreign currency translation adjustments net of
$0 tax in 2017, 2018 and 2019
Unrealized gains on available-for-sale securities,
net of $0 tax in 2017, 2018 and 2019
Release of foreign currency translation
adjustments on contribution of subsidiary into
equity method investment
Total other comprehensive income (loss)
Comprehensive income (loss)
$
(79,237) $
(2,154) $ (81,391) $
(3,790) $
(5,393) $ (9,183) $
20,421
$
(7,162) $ 13,259
(113)
189
—
—
(113)
(1,305)
189
54
16,712
16,788
(62,449) $
$
—
—
16,712
16,788
(2,154) $ (64,603) $
—
(1,251)
(5,041) $
—
—
—
—
(1,305)
54
—
(1,251)
(5,393) $ (10,434) $
505
67
—
—
505
67
—
572
20,993
$
—
—
—
572
(7,162) $ 13,831
See accompanying notes to consolidated financial statements.
59
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’
EQUITY (In thousands, except share data)
Common stock
Shares
Amount
Additional
Paid-In
Capital
Accumulated
Other
Accumulated Comprehensive
Deficit
Income (Loss)
Noncontrolling
Interest in
Subsidiary
Stockholders’
Total
Equity
Balance, December 31, 2016
145,538,063 $
15 $ 1,090,361 $ (603,836) $
(17,675) $
24,822 $ 493,687
Cumulative effect of adopting ASU 2016-09 and
ASU 2016-16 (Note 1)
Balance, January 1, 2017
Issuance of common stock, net of offering costs
Stock-based compensation
Net loss
Other comprehensive income
Balance, December 31, 2017
Cumulative effect of adopting ASU 2014-09 (Note
1)
Balance, January 1, 2018
Issuance of common stock, net of offering costs
Stock-based compensation
Net loss
Other comprehensive loss
Increase in ownership in subsidiary
Balance, December 31, 2018
Issuance of common stock, net of offering costs
Stock-based compensation
Net income (loss)
Other comprehensive income
Increase in ownership in subsidiary
—
145,538,063
6,112,906
—
—
—
151,650,969
—
151,650,969
51,948,923
—
—
—
—
203,599,892
1,123,163
—
—
—
—
Balance, December 31, 2019
204,723,055 $
—
15
—
—
—
—
15
194
1,090,555
12,454
8,423
—
—
1,111,432
(497)
(604,333)
—
—
(79,237)
—
(683,570)
—
(17,675)
—
—
—
16,788
(887)
—
24,822
—
—
(2,154)
—
22,668
(303)
493,384
12,454
8,423
(81,391)
16,788
449,658
—
1,111,432
81,766
5,307
—
—
264
1,198,769
309
3,880
—
—
228
—
15
5
—
—
—
—
20
—
—
—
—
—
20 $ 1,203,186 $ (668,232) $
(1,293)
(684,863)
—
—
(3,790)
—
—
(688,653)
—
—
20,421
—
—
—
(887)
—
—
—
(1,251)
—
(2,138)
—
—
—
572
—
(1,566) $
—
22,668
—
—
(1,293)
448,365
81,771
5,307
(9,183)
(1,251)
—
525,009
309
3,880
13,259
572
—
9,621 $ 543,029
(5,393)
—
(264)
17,011
—
—
(7,162)
—
(228)
See accompanying notes to consolidated financial statements.
60
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
Cash flows from operating activities:
Net income (loss)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating
activities:
Depreciation and amortization
Provision for doubtful accounts, notes and inventory
Stock-based compensation expense
Change in fair value of derivative instruments
Amortization of discount and debt issuance cost
Loss (gain) on disposal of property and equipment
Gain on extinguishment of debt, net
Gain from sale of certain assets of subsidiary
Asset impairments and other charges
Loss from formation of equity method investment
Loss from equity method investments
Right-of-use asset amortization
Deferred income taxes
Changes in operating assets and liabilities, net of assets and liabilities acquired and disposed:
Accounts and other receivables
Inventory
Prepaid expenses and other assets
Operating lease liabilities
Accounts payable
Deferred revenue
Accrued expenses and other
Net cash provided by (used in) operating activities
Cash flows from investing activities:
Purchases of short-term investments
Maturities and sales of short-term investments
Purchases of and deposits on property and equipment
Loans made to customers
Payments on and proceeds from sales of loans receivable
Cash received from sale of certain assets of subsidiary, net
Cash contributed in formation of equity method investment
Investments in other entities
Proceeds from disposal of property and equipment
Net cash provided by (used in) investing activities
Cash flows from financing activities:
Issuances of common stock
Fees paid for issuances of common stock, debt prepayment and debt issuance costs
Proceeds from debt instruments and finance lease obligations
Proceeds from revolving line of credit
Repayments of borrowing under revolving line of credit
Repayments of debt instruments and finance lease obligations
Payments to holders of stock options in subsidiaries
Net cash provided by (used in) financing activities
Effect of exchange rates on cash, cash equivalents, and restricted cash
Net increase (decrease) in cash, cash equivalents and restricted cash
Cash, cash equivalents and restricted cash, beginning of year
Cash, cash equivalents and restricted cash, end of year
Supplemental disclosure of cash flow information:
Income taxes paid
Interest paid, net of $103, $244 and $441 capitalized, respectively
Year Ended December 31,
2018
2017
2019
$
(81,391) $
(9,183) $
13,259
56,614
19,835
8,123
(46)
847
3,105
(3,195)
(70,658)
58,061
6,465
131
—
(2,400)
6,881
963
6,753
—
(8,964)
9,268
(14,709)
(4,317)
(340,194)
272,220
(36,307)
(894)
1,102
149,088
(2,404)
(1,928)
—
40,683
51,850
1,857
5,307
(9,788)
(1,220)
2,554
—
(4,782)
—
1,163
2,723
—
—
(6,360)
(1,065)
1,547
—
679
30
2,670
37,982
(348,091)
425,804
(25,263)
—
518
871
—
—
530
54,369
10,767
(638)
9,765
312
(23,812)
(30,707)
(8,850)
(43,163)
890
(5,907)
43,115
37,208 $
83,438
(1,004)
17,243
—
—
(194,886)
—
(95,209)
274
(2,584)
37,208
34,624 $
49,625
2,586
3,880
5,545
(728)
(2,536)
—
(7,455)
—
—
119
3,234
738
(63,408)
3,439
(16,617)
(3,786)
9,316
(3,528)
18,596
12,279
(171,080)
180,704
(27,088)
—
608
7,582
—
—
7,772
(1,502)
309
(123)
15,294
—
—
(7,795)
—
7,685
136
18,598
34,624
53,222
344 $
17,048 $
257 $
16,751 $
36
6,788
$
$
$
See accompanying notes to consolidated financial statements.
61
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 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,” unless the context or the use of the term indicates or requires otherwise) is engaged in the business
of selling natural gas as an alternative fuel for vehicle fleets and related natural gas fueling solutions to its customers,
primarily in the United States and Canada.
The Company’s principal business is supplying renewable natural gas (“RNG”), compressed natural gas (“CNG”) and
liquefied natural gas (“LNG”) (RNG is delivered in the form of CNG or LNG) for light, medium and heavy-duty vehicles
and providing operation and maintenance (“O&M”) services for public and private vehicle fleet customer stations. As a
comprehensive solution provider, the Company also designs, builds, operates and maintains fueling stations; sells and
services natural gas fueling compressors and other equipment used in CNG stations and LNG stations; offers assessment,
design and modification solutions to provide operators with code-compliant service and maintenance facilities for natural
gas vehicle fleets; transports and sells CNG and LNG via “virtual” natural gas pipelines and interconnects; procures and
sells RNG; sells tradable credits it generates by selling RNG and conventional natural gas as a vehicle fuel, including
Renewable Identification Numbers (“RIN Credits” or “RINs”) under the federal Renewable Fuel Standard Phase 2 and
credits under the California and the Oregon Low Carbon Fuel Standards (collectively, “LCFS Credits”); helps its
customers acquire and finance natural gas vehicles; and obtains federal, state and local credits, grants and incentives. In
addition, for all periods presented before March 31, 2017, the Company produced RNG at its own production facilities,
and for all periods presented before December 29, 2017, the Company manufactured natural gas fueling compressors and
other equipment used in CNG stations. See Note 4 for more information.
Basis of Presentation
The accompanying consolidated financial statements include the accounts of the Company and its subsidiaries, and,
in the opinion of management, reflect all adjustments, which include only normal recurring adjustments, necessary to state
fairly the Company’s consolidated financial position, results of operations, comprehensive loss and cash flows in
accordance with accounting principles generally accepted in the United States of America (“US GAAP”). All
intercompany accounts and transactions have been eliminated in consolidation.
Reclassifications
The prior period amounts of the current portion of finance lease obligations, $0.7 million, and the long-term portion
of finance lease obligations, $3.8 million, have been reclassified to be presented separately in the consolidated balance
sheets to conform to the current period presentation. Deferred income taxes of $2.4 million for the year ended
December 31, 2017 have been reclassified to be presented separately in the consolidated statements of cash flows to
conform to the current year presentation. These reclassifications had no material effect on the Company’s consolidated
financial position, results of operations, or cash flows as previously reported.
Use of Estimates
The preparation of consolidated financial statements in conformity with US GAAP requires management to make
estimates and assumptions that affect the amounts reported in the accompanying consolidated financial statements and
these notes. Actual results could differ from those estimates and may result in material effects on the Company’s operating
results and financial position. Significant estimates made in preparing the accompanying consolidated financial statements
include (but are not limited to) those related to revenue recognition, fair value measurements, goodwill and long-lived
asset valuations and impairment assessments, income tax valuations and stock-based compensation expense.
62
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Inventory
Inventory consists of raw materials and spare parts, work in process and finished goods and is stated at the lower of
cost (first-in, first-out) or net realizable value. The Company evaluates inventory balances for excess quantities and
obsolescence by analyzing estimated demand, inventory on hand, sales levels and other information and reduces inventory
balances to net realizable value for excess and obsolete inventory based on this analysis.
Inventories consisted of the following as of December 31, 2018 and 2019 (in thousands):
Raw materials and spare parts
Finished goods
Total inventory
Derivative Instruments and Hedging Activities
2018
34,890 $
85
34,975 $
2019
29,874
—
29,874
$
$
In connection with the Company’s Zero Now truck financing program, the Company entered into commodity swap
contracts in October 2018 intended to manage risks related to the diesel-to-natural gas price spread in connection with the
natural gas fuel supply commitments the Company expects to make in its anticipated fueling agreements with fleet
operators that participate in the Zero Now program. The Company has not designated any derivative instruments as hedges
for accounting purposes and does not enter into such instruments for speculative trading purposes. These derivative
instruments are recorded in the accompanying consolidated balance sheets and are measured as either an asset or liability
at fair value with changes in fair value recognized in earnings. See Note 8 for more information.
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 three to twenty years
for LNG liquefaction plant assets, up to 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 $4.4 million, $0.7 million, and $1.6 million for the years ended December 31, 2017,
2018, and 2019, respectively.
Long-Lived Assets
The Company reviews the carrying value of its long-lived assets, including property and equipment and intangible
assets with finite useful lives, for impairment whenever events or changes in circumstances indicate that the carrying value
of an asset or asset group may not be recoverable. Events that could result in an impairment review include, among others,
a significant decrease in the operating performance of a long-lived asset or asset group or the decision to close a fueling
station. Impairment testing involves a comparison of the sum of the undiscounted future cash flows of the asset or asset
group to its carrying amount. If the sum of the undiscounted future cash flows exceeds the carrying amount, then no
impairment exists. If the carrying amount exceeds the sum of the undiscounted future cash flows, then a second step is
performed to determine the amount of impairment, if any, to be recognized. An impairment loss is recognized to the extent
that the carrying amount of the asset or asset group exceeds its fair value. The fair value of the asset or asset group is based
on estimated discounted future cash flows of the asset or asset group using a discount rate commensurate with the related
risk. The estimate of future cash flows requires management to make assumptions and to apply judgment, including
forecasting future sales and expenses and estimating useful lives of the assets. These estimates can be affected by a number
of factors, including, among others, future results, demand, and economic conditions, many of which can be difficult to
predict.
63
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
There were no impairments of the Company’s long-lived assets in the years ended December 31, 2018 and 2019. In
the third quarter of the year ended December 31, 2017, the Company recorded asset impairment charges of $32.3 million
related to its then-subsidiary, IMW Industries Ltd. (“IMW”) (formerly known as Clean Energy Compression Corp.)
(“CEC”) and $20.4 million related to certain station closures (see Note 3 for more information).
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 from one to eight years for customer
relationships, one to ten years for acquired contracts, two to ten years for trademarks and trade names, and three years for
non-compete agreements.
The Company’s intangible assets as of December 31, 2018 and 2019 were as follows (in thousands):
Customer relationships
Acquired contracts
Trademark and trade names
Non-compete agreements
Total intangible assets
Less accumulated amortization
Net intangible assets
$
2018
5,376 $
4,384
2,700
860
13,320
(11,113)
$
2,207 $
2019
5,376
4,384
2,700
860
13,320
(12,091)
1,229
Amortization expense for intangible assets was $5.1 million, $1.4 million, and $1.0 million for the years ended
December 31, 2017, 2018, and 2019, respectively. Estimated amortization expense for the two years succeeding the year
ended December 31, 2019 is approximately $0.8 million in 2020 and $0.5 million in 2021.
Goodwill
Goodwill represents the excess of costs incurred over the fair value of the net assets of acquired businesses. The
Company assesses its goodwill using either a qualitative or quantitative approach to determine whether it is more likely
than not that the fair value of its reporting unit is less than its carrying value. The Company is required to use judgment
when applying the goodwill impairment test, including, among other considerations, the identification of reporting unit(s),
the assessment of qualitative factors, and the estimation of fair value of a reporting unit in the quantitative approach. The
Company determined that it is a single reporting unit for the purpose of goodwill impairment tests. The Company performs
the impairment test annually on October 1, or more frequently if facts and circumstances warrant a review.
The qualitative goodwill assessment includes the potential impact on a reporting unit’s fair value of certain events and
circumstances, including its enterprise value, macroeconomic conditions, industry and market considerations, cost factors,
and other relevant entity-specific events. If it is determined, based upon the qualitative assessment, that it is more likely
than not that the reporting unit’s fair value is less than its carrying amount, then a quantitative impairment test is performed.
The quantitative assessment estimates the reporting unit’s fair value based on its enterprise value plus an assumed
control premium as evidence of fair value. The estimates used to determine the fair value of the reporting unit may change
based on results of operations, macroeconomic conditions, stock price fluctuations, or other factors. Changes in these
estimates could materially affect our assessment of the fair value and goodwill impairment for the reporting unit.
During the years ended December 31, 2018 and 2019, the Company utilized the quantitative approach and concluded
there were no indicators of impairment to goodwill.
During the third quarter of the year ended December 31, 2017, as a result of the asset impairment charges recorded
for intangible assets and stations (described previously and in Note 3), the Company determined that sufficient indicators
of potential impairment existed to require an interim goodwill test of its one reporting unit prior to the annual test performed
64
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
in the fourth quarter of 2017. The goodwill test was performed by computing the fair value of the reporting unit and
comparing it to the carrying value using a quantitative assessment. Based on the results of the goodwill test, the Company
concluded that it was more likely than not that the fair value of its reporting unit exceeded its carrying amount and thus no
impairment existed. The annual impairment test was subsequently performed on October 1 using the quantitative
assessment and the Company concluded no impairment existed.
The following table summarizes the activity related to the carrying amount of goodwill (in thousands):
Balance as of December 31, 2017
Balance as of December 31, 2018
Balance as of December 31, 2019
Revenue Recognition
$
$
$
64,328
64,328
64,328
On January 1, 2018, the Company adopted Financial Accounting Standards Board (“FASB”) Accounting Standards
Update (“ASU”) 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASC 606”), using the modified
retrospective method and recognized the cumulative effect of initially applying ASC 606 as an adjustment to
“Accumulated deficit” as of January 1, 2018. The reported results for the years ended December 31, 2018 and 2019 are
presented under ASC 606, while the reported results for periods prior to January 1, 2018 are not adjusted and were prepared
in accordance with ASC 605, Revenue Recognition. The adoption of ASC 606 did not have a material impact on the
Company’s consolidated financial statements.
The ASC 606 adoption adjustments are as follows, and relate to significant financing components resulting from an
advance payment by a customer of the Company’s subsidiary, NG Advantage LLC (“NG Advantage”) and an extended
payment term to a station construction customer (in thousands):
Balance as of
Adjustments
Balance as of
Notes receivable and other long-term assets, net
Deferred revenue
Accumulated deficit
December 31, 2017 due to ASC 606
21,397 $
$
$
3,432 $
(683,570) $
$
(963) $
330 $
(1,293) $
January 1, 2018
20,434
3,762
(684,863)
The Company recognizes revenue when control of the promised goods or services is transferred to its customers, in
an amount that reflects the consideration to which it expects to be entitled in exchange for the goods or services. In order
to achieve that core principle, a five-step approach is applied: (1) identify the contract with a customer, (2) identify the
performance obligations in the contract, (3) determine the transaction price, (4) allocate the transaction price to the
performance obligations in the contract, and (5) recognize revenue allocated to each performance obligation when the
Company satisfies the performance obligation. A performance obligation is a promise in a contract to transfer a distinct
good or service to the customer and is the unit of account for revenue recognition.
The Company is generally the principal in its customer contracts because it has control over the goods and services
prior to them being transferred to the customer, and as such, revenue is recognized on a gross basis. Sales and usage-based
taxes are excluded from revenues. Revenue is recognized net of allowances for returns and any taxes collected from
customers, which are subsequently remitted to governmental authorities.
Volume-Related
The Company’s volume-related revenue primarily consists of sales of RNG, CNG and LNG fuel, O&M services and
RINs and LCFS Credits in addition to changes in fair value of the Company’s derivative instruments associated with
providing natural gas to customers under fueling contracts.
65
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Fuel and O&M services are sold pursuant to contractual commitments over defined goods-and-service delivery
periods. These contracts typically include a stand-ready obligation to supply natural gas and/or provide O&M services
daily based on a committed and agreed upon routine maintenance schedule or when and if called upon by the customer.
The Company applies the ‘right to invoice’ practical expedient and recognizes fuel and O&M services revenue in the
amount to which the Company has the right to invoice. The Company has a right to consideration based on the amount of
gasoline gallon equivalents of natural gas dispensed by the customer and current pricing conditions, which are typically
billed to the customer on a monthly basis. Since payment terms are less than a year, the Company has elected the practical
expedient which allows it to not assess whether a customer contract has a significant financing component.
Contract modifications are not distinct from the existing contract and are typically renewals of fuel and O&M service
sales. As a result, these modifications are accounted for as if they were part of the existing contract. The effect of a contract
modification on the transaction price is recognized prospectively.
The Company sells RINs and LCFS Credits to third parties that need the credits to comply with federal and state
requirements. Revenue is recognized on these credits when there is an agreement in place to monetize the credits at a
determinable price.
The changes in fair value of derivative instruments relate to the Company’s commodity swap and customer fueling
contracts. The contracts are measured at fair value with changes in the fair value recorded in the accompanying
consolidated statements of operations in the period incurred. The amounts are classified as revenue because the Company’s
commodity swap contracts are used to economically offset the risk associated with the diesel-to-natural gas price spread
resulting from anticipated customer fueling contracts under the Company’s Zero Now truck financing program. See Note 8
for more information about these derivative instruments. For the years ended December 31, 2018 and 2019, changes in the
fair value of commodity swaps and customer contracts amounted to a gain of $10.3 million and a loss of $(6.6) million,
respectively. No amounts were recognized in 2017 as the inception of these arrangements was October 2018.
Station Construction Sales
Station construction contracts are generally short-term, except for certain larger and more complex stations, which
can take up to 24 months to complete. For most of the Company’s station construction contracts, the customer contracts
with the Company to provide a significant service of integrating a complex set of tasks and components into a single
station. Hence, the entire contract is accounted for as one performance obligation.
The Company recognizes revenue over time as the Company performs under its station construction contracts because
of the continual transfer of control of the goods to the customer, who typically controls the work in process. Revenue is
recognized based on the extent of progress towards completion of the performance obligation and is recorded
proportionally as costs are incurred. Costs to fulfill the Company’s obligations under these contracts typically include
labor, materials and subcontractors’ costs, other direct costs and an allocation of indirect costs.
Refinements of estimates to account for changing conditions and new developments are continuous and characteristic
of the process. Many factors that can affect contract profitability may change during the performance period of the contract,
including differing site conditions, the availability of skilled contract labor, the performance of major suppliers and
subcontractors, and unexpected changes in material costs. Because a significant change in one or more of these estimates
could affect the profitability of these contracts, the contract price and cost estimates are reviewed periodically as work
progresses and adjustments proportionate to the cost-to-cost measure of progress are reflected in contract revenues in the
reporting period when such estimates are revised as discussed above. Provisions for estimated losses on uncompleted
contracts are recorded in the period in which the losses become known.
Contract modifications are typically expansions in scope of an existing station construction project. As a result, these
modifications are accounted for as if they were part of the existing contract. The effect of a contract modification on the
66
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
transaction price and the Company’s measure of progress for the performance obligation to which it relates is recognized
as an adjustment to revenue (either as an increase or a reduction) on a cumulative catch-up basis.
Under the typical payment terms of the Company’s station construction contracts, the customer makes either
performance-based payments (“PBPs”) or progress payments. PBPs are interim payments of the contract price based on
quantifiable measures of performance or the achievement of specified events or milestones. Progress payments are interim
payments of costs incurred as the work progresses. For some of these contracts, the Company may be entitled to receive
an advance payment. The advance payment typically is not considered a significant financing component because it is
used to meet working capital demands that can be higher in the early stages of a construction contract and to protect the
Company if the customer fails to adequately complete some or all of its obligations under the contract. In addition, the
customer retains a small portion of the contract price until completion of the contract. Such retained portion of the contract
price is not considered a significant financing component because the intent is to protect the customer.
In certain contracts with its customers, the Company agrees to provide multiple goods or services, including
construction of and sale of a station, O&M services, and sale of fuel to the customer. These contracts have multiple
performance obligations because the promise to transfer each separate good or service is separately identifiable and is
distinct. This evaluation requires significant judgment and the decision to combine a group of contracts or separate the
combined or single contract into multiple performance obligations could change the amount of revenue recognized in one
or more periods.
The Company allocates the contract price to each performance obligation using best estimates of the standalone selling
price of each distinct good or service in the contract. The primary method used to estimate the standalone selling price for
fuel and O&M services is observable standalone sales, and the primary method used to estimate the standalone selling
price for station construction sales is the expected cost plus a margin approach because the Company sells customized
customer-specific solutions. Under this approach, the Company forecasts expected costs of satisfying a performance
obligation and then adds an appropriate margin for the good or service.
AFTC
See discussion under “Alternative Fuels Tax Credit” below for more information about AFTC, which is not recognized
as revenue until the period the credit is authorized through federal legislation.
Other
The majority of other revenue is from sales of used natural gas heavy-duty trucks purchased by the Company. Revenue
on these contracts is recognized at the point in time when the customer accepts delivery of the truck.
Alternative Fuels Tax Credit
Under separate pieces of U.S. federal legislation, the Company has been eligible to receive a federal alternative fuels
tax credit (“AFTC”) for its natural gas vehicle fuel sales made between October 1, 2006 and December 31, 2019. The
AFTC, which had previously expired on December 31, 2016, was reinstated on February 9, 2018 to apply retroactively to
vehicle fuel sales made from January 1, 2017 through December 31, 2017. On December 20, 2019, AFTC was
retroactively extended beginning January 1, 2018 through December 31, 2020. The AFTC credit is equal to $0.50 per
gasoline gallon equivalent of CNG that the Company sold as vehicle fuel, and $0.50 per diesel gallon of LNG that the
Company sold as vehicle fuel in 2017, 2018 and 2019.
Based on the service relationship with its customers, either the Company or its customer claims the credit. The
Company records its AFTC credits, if any, as revenue in its consolidated statements of operations because the credits are
fully payable to the Company and do not offset income tax liabilities. As such, the credits are not deemed income tax
credits under the accounting guidance applicable to income taxes.
67
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
As a result of the most recent legislation authorizing AFTC being signed into law on December 20, 2019, all AFTC
revenue for vehicle fuel the Company sold in the 2018 and 2019 calendar years, totaling $47.1 million, was recognized
during the year ended December 31, 2019. As a result of the previous legislation authorizing AFTC being signed into law
on February 9, 2018, all AFTC revenue for vehicle fuel the Company sold in the 2017 calendar year, totaling $25.2 million,
was recognized and collected during the year ended December 31, 2018. In addition, during the year ended December 31,
2018, the Internal Revenue Service (“IRS”) approved, and the Company recognized as revenue, $1.5 million of AFTC
credit claims related to prior years. The Company recognized no AFTC revenue for the year ended December 31, 2017.
AFTC is currently available through December 31, 2020 and may not be reinstated for vehicle fuel sales made after that
date.
LNG Transportation Costs
The Company records the costs incurred to transport LNG to its customers in “Product cost of sales” in the
accompanying consolidated statements of operations.
Advertising Costs
Advertising costs are expensed as incurred. Advertising costs were $0.3 million, $0.9 million and $1.2 million for
the years ended December 31, 2017, 2018, and 2019, respectively.
Stock-Based Compensation
The Company recognizes compensation expense for all stock‑based payment arrangements 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
award, stock price volatility and risk‑free interest rate. For restricted stock units, the Company determines the grant date
fair value based on the closing market price of its common stock on the date of grant.
In March 2016, the FASB issued ASU 2016-09, Compensation – Stock Compensation (Topic 718): Improvements to
Employee Share-Based Payments Accounting, which simplified the accounting for share-based payment transactions. The
Company adopted the standard as of January 1, 2017 and in connection with the adoption, elected to recognize forfeitures
when they occur. This election was implemented under the modified retrospective approach with a cumulative effect of
an increase in accumulated deficit of $0.2 million, net of tax. This adjustment represents the cumulative additional
compensation expense that would have been recognized through the date of adoption
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 carrying amounts of existing 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. Valuation allowances are established when management
determines it is more likely than not that deferred tax 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 US GAAP income and the
amounts and estimated timing of the reversal of any deferred tax assets and liabilities.
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
68
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
likelihood of being realized upon ultimate settlement. The Company recognizes potential accrued interest and penalties
related to unrecognized tax benefit in income tax expense.
The Company operates within multiple domestic and foreign taxing jurisdictions and is subject to audit in these
jurisdictions. These audits can involve complex issues, which may require an extended period of time to resolve. Although
the Company believes that adequate consideration has been given to these issues, it is possible that the ultimate resolution
of these issues could be significantly different from originally estimated.
In October 2016, the FASB issued ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other
Than Inventory. Under the new standard, the selling (transferring) entity is required to recognize a current tax expense or
benefit upon transfer of the asset. Similarly, the purchasing (receiving) entity is required to recognize a deferred tax asset
or liability, as well as the related deferred tax benefit or expense, upon purchase or receipt of the asset. The Company early
adopted the standard as of January 1, 2017. This election was implemented under the modified retrospective approach,
resulting in a $0.3 million increase in accumulated deficit representing the cumulative recognition of the income tax
consequences of intra-entity transfers of assets other than inventory that occurred before the adoption date.
Net Income (Loss) Per Share
Basic net income (loss) per share is computed by dividing the net income (loss) attributable to Clean Energy Fuels
Corp. by the weighted-average number of common shares outstanding and common shares issuable for little or no cash
consideration during the period. Diluted net income (loss) per share is computed by dividing the net loss attributable to
Clean Energy Fuels Corp. by the weighted-average number of common shares outstanding and common shares issuable
for little or no cash consideration during the period and potentially dilutive securities outstanding during the period, and
therefore reflects the dilution from common shares that may be issued upon exercise or conversion of these potentially
dilutive securities, such as stock options, warrants, convertible notes and restricted stock units. The dilutive effect of stock
awards and warrants is computed under the treasury stock method. The dilutive effect of convertible notes and restricted
stock units is computed under the if-converted method. Potentially dilutive securities are excluded from the computations
of diluted net income (loss) per share if their effect would be antidilutive.
Foreign Currency Translation and Transactions
The Company uses the local currency as the functional currency of its foreign subsidiary and equity method
investment. 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. 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 its consolidated
statements of operations. For the years ended December 31, 2017, 2018, and 2019, foreign exchange transaction gains and
(losses) were included in “Other income (expense), net” in the accompanying consolidated statements of operations and
were $(0.2) million, $(0.0) million and $0.0 million, respectively.
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 (loss)
and comprehensive income (loss) for the years ended December 31, 2017, 2018, and 2019 was comprised of the
Company’s foreign currency translation adjustments and unrealized gains and losses on available-for-sale securities.
69
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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. Certain
international customers, however, have historically been slower to pay on trade receivables. Accordingly, the Company
continually 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. Although 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 Accounting Standards
Recently Adopted Accounting Changes
In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) (“ASC 842”), which amends the guidance in
former Accounting Standards Codification Topic 840, Leases (“ASC 840”). The new standard requires most leases to be
recognized on the balance sheet, which will increase reported assets and liabilities. Accounting for lessors and capital
leases (now known as finance leases) is substantially similar to ASC 840. The new standard is effective for annual and
interim periods in fiscal years beginning after December 15, 2018, which for the Company was the first quarter of 2019.
The Company adopted this standard using the modified retrospective transition method. Results for reporting periods
beginning after January 1, 2019 are presented under ASC 842, while prior period amounts are not adjusted. This adoption
had a material effect on the Company’s consolidated balance sheets as a result of recording ROU assets and lease liabilities
for existing operating leases on the consolidated balance sheets. The adoption did not have a material effect on the
Company’s consolidated statements of operations or its consolidated statements of cash flows.
As permitted under ASC 842, the Company elected the package of practical expedients that permit it to not reassess
(1) whether an existing contract is or contains a lease, (2) the classification of existing leases, and (3) whether previously
capitalized costs continue to qualify as initial indirect costs. The Company also elected the practical expedient allowing it
to use hindsight in determining the lease term and in assessing the likelihood a purchase option will be exercised.
The effect of adopting ASC 842 was as follows (in thousands):
Balance as of
December 31, 2018
$
$
$
$
— $
— $
48,469 $
15,035 $
Adjustments
Due to ASC 842
Balance as of
January 1, 2019
24,453
25,943
47,973
14,041
24,453 $
25,943 $
(496) $
(994) $
Operating lease right-of-use assets
Operating lease obligations
Accrued liabilities
Other long-term liabilities
Recently Issued Accounting Standards
In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement
of Credit Losses on Financial Instruments. The new standard amends the impairment model to utilize an expected loss
methodology in place of the currently used incurred loss methodology, which will result in the more timely recognition of
losses. This pronouncement is effective for reporting periods beginning after December 15, 2019. The Company will adopt
this standard in the first quarter of 2020. The Company does not expect adoption of this ASU to have a material impact on
its consolidated financial statements and related disclosures.
70
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Note 2 —Revenue from Contracts with Customers
Disaggregation of Revenue
The table below presents the Company’s revenue disaggregated by revenue source (in thousands):
Years Ended December 31,
2018
2019
2017
Volume-related (1)
Station construction sales
AFTC
Compressor sales (2)
Other
Total revenue
$ 264,880 $ 286,684 $ 273,535
23,120
47,123
—
287
$ 341,599 $ 346,419 $ 344,065
51,854
—
23,527
1,338
25,501
26,729
—
7,505
(1) Includes changes in fair value of derivative instruments related to the Company’s commodity swap and customer fueling contracts. See Note 1 and
Note 8 for more information about these derivative instruments. For the years ended December 31, 2018 and 2019, changes in the fair value of
commodity swaps and customer fueling contracts amounted to a gain of $10.3 million and a loss of $6.6 million, respectively.
(2) The Company completed the CEC Combination (as defined in Note 4) during the year ended December 31, 2017 and no longer generates revenue
from compressor sales.
Remaining Performance Obligations
Remaining performance obligations represent the transaction price of customer orders for which the work has not
been performed. As of December 31, 2019, the aggregate amount of the transaction price allocated to remaining
performance obligations was $15.8 million, which related to the Company’s station construction sale contracts. The
Company expects to recognize revenue on the remaining performance obligations under these contracts over the next 12
to 24 months.
For volume-related revenue, the Company has elected to apply an optional exemption, which waives the requirement
to disclose the remaining performance obligation for revenue recognized through the ‘right to invoice’ practical expedient.
Costs to Fulfill a Contract
The Company capitalizes costs incurred to fulfill its contracts that (1) relate directly to the contract, (2) are expected
to generate resources that will be used to satisfy the Company’s performance obligations under the contract, and (3) are
expected to be recovered through revenue generated under the contract. Contract fulfillment costs are recorded to
depreciation expense as the Company satisfies its performance obligations over the term of the contract. These costs
primarily relate to set-up and other direct installation costs incurred by NG Advantage, for equipment that must be installed
on customers’ land before NG Advantage, LLC (“NG Advantage”) is able to deliver CNG to the customer because the
customer does not have direct access to the natural gas pipelines. These costs are classified in “Land, property, and
equipment, net” in the accompanying consolidated balance sheets. As of December 31, 2018 and 2019, these capitalized
costs incurred to fulfill contracts were $9.1 million and $10.2 million with accumulated depreciation of $4.9 million and
$6.3 million, respectively, and related depreciation expense of $2.0 million and $2.2 million for the years ended
December 31, 2018 and 2019, respectively.
Contract Balances
The timing of revenue recognition, billings and cash collections results in billed accounts receivable, unbilled
receivables (contract assets), and customer advances and deposits (contract liabilities) in the accompanying consolidated
71
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
balance sheets. Changes in the contract asset and liability balances during the year ended December 31, 2019, were not
materially affected by any factors outside the normal course of business.
As of December 31, 2018 and 2019, the Company’s contract balances were as follows (in thousands):
Accounts receivable, net
Contract assets - current
Contract assets - non-current
Contract assets - total
Contract liabilities - current
Contract liabilities - non-current
Contract liabilities - total
Accounts Receivable, Net
$
$
$
$
$
2018
68,865 $
2019
61,760
656 $
3,825
4,481 $
5,513 $
9,844
15,357 $
455
3,777
4,232
5,329
6,339
11,668
“Accounts receivable, net” in the accompanying consolidated balance sheets include amounts billed and currently due
from customers. The amounts due are stated at their net estimated realizable value. The Company maintains an allowance
for doubtful accounts to provide for the estimated amount of receivables that will not be collected. The allowance is based
upon an assessment of customer creditworthiness, historical payment experience, and the age of outstanding receivables.
Contract Assets
Contract assets include unbilled amounts typically resulting from the Company’s station construction sale contracts,
when the cost-to-cost method of revenue recognition is utilized and revenue recognized exceeds the amount billed to the
customer, and right to payment is not just subject to the passage of time. Amounts may not exceed their net realizable
value. Contract assets are classified as current or noncurrent based on the timing of billings. The current portion is included
in “Prepaid expenses and other current assets” and the noncurrent portion is included in “Notes receivable and other long-
term assets, net” in the accompanying consolidated balance sheets.
Contract Liabilities
Contract liabilities consist of billings in excess of revenue recognized from the Company’s station construction sale
contracts and payments primarily from a customer of NG Advantage in advance of the performance obligations. Billings
in excess of revenue recognized of $2.0 million and $1.8 million and advance payments of $3.5 million and $3.5 million
are classified as current as of December 31, 2018 and 2019, respectively. Deferred revenue is classified as current or
noncurrent based on when the revenue is expected to be recognized. The current portion and noncurrent portion of deferred
revenue are included in “Deferred revenue” and “Other long-term liabilities,” respectively, in the accompanying
consolidated balance sheets.
The increase in the contract liabilities balance for the year ended December 31, 2019 is primarily driven by billings
in excess of revenue recognized, offset by $5.9 million of revenue recognized related to the Company’s contract liability
balances as of December 31, 2018.
Note 3 —Asset Impairments, Other Charges, and Inventory Valuation Provision
In light of continued low oil prices and the state of natural gas vehicle adoption, among other factors, during the third
quarter of the year ended December 31, 2017, the Company undertook an evaluation of its operations with the intent of
minimizing and eliminating assets it believed were underperforming. As a result of this evaluation, the Company identified
72
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
certain of its fueling stations where the current and projected natural gas volume and profitability levels were not expected
to be sufficient to support the Company’s investment in the fueling station assets, and the Company decided to close these
stations. The Company also reduced its workforce and took other steps to reduce overhead costs as a result of this
evaluation, in an effort to lower its operating expenses going forward. In addition, this evaluation resulted in a strategic
shift in how the Company viewed its natural gas compressor manufacturing business, operated by CEC. In an effort to
increase the scale and reach and improve the financial prospects of the Company’s investment in this business, the
Company entered into an investment agreement with a strategic partner in November 2017, pursuant to which both parties
combined their respective natural gas compressor manufacturing businesses (see Note 4 for more information). As a result
of these decisions and the steps taken to implement them, during the year ended December 31, 2017, the Company incurred
on a pre-tax basis, aggregate cash and non-cash charges related to asset impairments and other charges, and a non-cash
inventory valuation charge. In addition, the Company incurred a cash charge for payments made as a result of temporary
restrictions on its LCFS Credits account during the fourth quarter of 2017.
The following table summarizes these charges (in thousands):
Workforce reduction and related charges
CEC asset impairments
Station closures and related charges
LCFS Credits charge
Total asset impairments and other charges
Inventory valuation provision
Total charges
Cash Charges
Year Ended
December 31, 2017
3,057
32,274
25,557
7,046
67,934
13,158
81,092
$
$
The following table summarizes the charges related to the foregoing that have been or will be settled with cash
payments and their related liability balances as of December 31, 2018 and 2019 (in thousands):
Cash Payments
Made in the
Year Ended
Balance as of
Cash Payments
Made in the
Year Ended
Balance as of
Cash Payments
Made in the
Year Ended
Balance as of
Employee severance
Lease termination fees and AROs for
station closures
Charges December 31, 2017 December 31, 2017 December 31, 2018 December 31, 2018 December 31, 2019 December 31, 2019
—
$ 2,757
(2,757) $
— $
— $
— $
— $
4,083
$ 6,840
(70)
(2,827) $
4,013
4,013 $
(1,810)
(1,810) $
2,203
2,203 $
(249)
(249) $
1,954
1,954
Workforce Reduction and Related Charges
As a result of the workforce reduction in 2017, severance costs of $2.8 million were incurred in connection with
employee terminations and $0.3 million in stock-based compensation expense was incurred for the associated acceleration
of certain stock awards.
Impairments of Long-Lived Assets
CEC: Asset Impairment Charges
Due to the continued low global demand for compressors, and the decision to position CEC’s compressor
manufacturing business for industry consolidation with a potential strategic partner, the Company’s management
determined that an impairment indicator was present for the long-lived assets of CEC. Recoverability was tested using
future cash flow projections based on management’s long-term estimates of market conditions. Based on the results of this
73
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
test, the sum of the undiscounted future cash flows was less than the carrying value of the CEC asset group. As a result,
these long-lived assets were written down to their respective fair values, resulting in an impairment charge of $32.3 million.
Fair value was based on expected future cash flows using Level 3 inputs. The cash flows are those expected to be generated
by market participants, discounted at an appropriate rate for the risks inherent in those cash flow projections.
Station Closures and Related Charges
During the third quarter of the year ended December 31, 2017, the Company decided to close 42 fueling stations by
December 31, 2017, which were performing below management’s expectations based on volume and profitability levels.
As a result, these station assets, which had an aggregate carrying value of $23.3 million, were written down to their
respective fair values of $2.9 million on an aggregate basis, resulting in a charge of $20.4 million. The fair values of these
assets were determined using the cost approach.
In addition, certain of these station closures triggered related other charges totaling $5.2 million, which consisted of
write-offs for any deferred losses, lease termination fees, and an increase in asset retirement obligations (“AROs”).
Due to the closure of these stations, the Company’s management assessed whether impairment indicators were present
for the long-lived assets of the Company’s other fueling stations. The Company determined there were no indicators of
impairment present among its remaining fueling stations and no further steps were required for an impairment evaluation
with respect to these stations.
Inventory Valuation Provision
As a result of the Company’s evaluation process to minimize and eliminate underperforming station assets, the
Company determined that $27.2 million of certain station parts which were historically classified as construction in
progress within “Land, property, and equipment, net” were to be reclassified as “Inventory” in the accompanying
consolidated balance sheets because they will primarily be used for stations to be sold. Subsequent to the reclassification,
the Company calculated and recorded a lower of cost or market non-cash charge of $7.8 million for these station
parts. Additionally, in conjunction with its decision to seek a strategic partner for CEC, the Company incurred a lower of
cost or market non-cash charge of $5.4 million for the inventory of CEC. The aggregate amount of $13.2 million is reported
as “Inventory valuation provision” in the accompanying consolidated statements of operations for the year ended
December 31, 2017.
LCFS Credits Cash Payments
The Company generates LCFS Credits when it sells RNG and conventional natural gas for use as a vehicle fuel and
can sell and transfer these credits to third parties. The California Air Resources Board (“CARB”) restricted the Company’s
ability to sell and transfer LCFS Credits during the third and fourth quarters of 2017 pending completion of an
administrative review. The Company was, however, required to settle preexisting contractual obligations to transfer LCFS
Credits to third parties by making cash payments totaling $7.0 million, the equivalent value of the LCFS Credits the
Company would have otherwise transferred to satisfy its obligations. These payments are reported in “Asset impairments
and other charges” in the accompanying consolidated statements of operations for the year ended December 31, 2017. In
November 2017, CARB invalidated certain LCFS Credits the Company had generated in prior periods and released the
restriction on the Company’s ability to sell and transfer LCFS Credits.
Note 4 —Divestitures
BP Transaction
On February 27, 2017, Clean Energy Renewable Fuels (“Renewables”) entered into an asset purchase agreement
(the “APA”) with BP Products North America (“BP”). Pursuant to the APA, Renewables agreed to sell to BP its assets
74
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
relating to its RNG production business (the “BP Transaction”), consisting of Renewables’ two RNG production facilities,
Renewables’ interest in joint ventures formed with a third-party to develop new RNG production facilities, and
Renewables’ third-party RNG supply contracts (the “Assets”). The BP Transaction was completed on March 31, 2017 for
a sale price of $155.5 million, plus BP assumed $8.8 million of debt.
On March 31, 2017, BP paid Renewables $30.0 million in cash and delivered to Renewables a promissory note with
a principal amount of $123.5 million, which was paid in full on April 3, 2017. In addition, as a result of the determination
of certain post-closing adjustments, (i) BP paid Renewables an additional $2.0 million on June 22, 2017, and (ii) the gain
recorded from the BP Transaction was reduced by $0.8 million. Pursuant to the APA, the valuation date of the BP
Transaction was January 1, 2017, and as a result, the APA included certain adjustments to the purchase price to reflect a
determination of the amount of cash accumulated by Renewables from the valuation date to the closing date, net of
permitted cash outflows. Control of the Assets was not transferred until the BP Transaction was completed on March 31,
2017. Accordingly, the full operating results of Renewables are included in the accompanying consolidated statements of
operations through March 31, 2017. The net cash proceeds from the BP Transaction were $142.2 million, net of $1.0
million cash transferred to BP, and the Company incurred $3.7 million in transaction fees in connection with the BP
Transaction.
The BP Transaction resulted in a total gain of $70.7 million, which was recorded in “Gain from sale of certain assets
of subsidiary” in the accompanying consolidated statements of operations for the year ended December 31, 2017. Included
in the determination of this gain amount is goodwill of $26.6 million allocated to the disposed assets based on the relative
fair values of the assets disposed and the portion of the retained reporting unit.
The Company determined that the BP Transaction did not meet the definition of a discontinued operation because the
disposal did not represent a strategic shift that will have a major effect on the Company’s operations and financial results.
In addition, under the APA, BP is required, following the closing of the BP Transaction, to pay Renewables up to an
additional $25.0 million in cash over a five-year period if certain conditions relating to the Assets are met. In
February 2018, the Company received $0.9 million in cash for its satisfaction of the performance criteria for the first period
under the APA, which ended on December 31, 2017. Upon its receipt of such cash, the Company paid $0.1 million in cash
and issued 15,877 shares of the Company’s common stock with a fair value of $0.0 million to former holders of options
to purchase membership units in Renewables. The performance criteria for the second period under the APA, which ended
on December 31, 2018, was also satisfied, and the Company received a cash payment of $5.4 million in March 2019.
During the year ended December 31, 2019, after receipt of the cash payment, the Company paid $0.6 million in cash to
former holders of options to purchase membership units in Renewables. In December 2019, the Company and BP entered
into an Amendment to the APA (“Amended APA”) which amended the earn-out for years four and five and paid the
Company an additional $2.8 million for year three of the earn-out period. As a result of the performance criteria for year
three under the APA being satisfied, and the additional $2.8 million received by the Company in December 2019 in
accordance with the Amended APA, the Company recognized a gross gain of $8.4 million and accrued amounts due to
former holders of options to purchase membership units in Renewables of $0.9 million as of December 31, 2019. The
Company recognized a net gain of $0.8 million, $4.8 million, and $7.5 million during the years ended December 31, 2017,
2018 and 2019, respectively, which is included in “Gain from sale of certain assets of subsidiary” in the accompanying
consolidated statements of operations. The net gain of $0.8 million during the year ended December 31, 2017 is included
in the total gain on the BP Transaction stated above.
As of December 31, 2019, the Company has paid $9.2 million in cash and issued 770,269 shares of the Company’s
common stock with a fair value of $2.0 million to former holders of options to purchase membership units in Renewables.
Following the completion of the BP Transaction, Renewables and the Company continue to procure RNG from BP
under a long-term supply contract (the “BP Supply Agreement”) and from other RNG suppliers, and resell such RNG
through the Company’s natural gas fueling infrastructure as Redeem, the Company’s RNG vehicle fuel. On October 1,
2018, Renewables and BP amended the BP Supply Agreement to extend the term and add additional RNG supply. BP and
75
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Renewables share in the RINs and LCFS Credits generated from the increased RNG supply sold through the Company’s
vehicle fueling infrastructure and to other customers. See Note 2 for information on revenue recognition of these credits.
SAFE&CEC S.r.l.
On November 26, 2017, the Company, through its former subsidiary, CEC, entered into an investment agreement with
Landi Renzo S.p.A. (“LR”), an alternative fuels company based in Italy. Pursuant to the investment agreement, the
Company and LR agreed to combine their respective natural gas compressor subsidiaries, CEC and SAFE S.p.A, in a new
company known as “SAFE&CEC S.r.l.” (such combination transaction is referred to as the “CEC Combination”).
SAFE&CEC S.r.l. is focused on manufacturing, selling and servicing natural gas fueling compressors and related
equipment for the global natural gas fueling market. Upon the closing of the CEC Combination on December 29, 2017,
the Company owns 49% of SAFE&CEC S.r.l. and LR owns 51% of SAFE&CEC S.r.l.
The Company accounts for its interest in SAFE&CEC S.r.l. using the equity method of accounting because the
Company does not control but has the ability to exercise significant influence over SAFE&CEC S.r.l.’s operations. The
fair value of the CEC Combination was determined using the income valuation approach. Under the income approach, the
Company used a discounted cash flow model (“DCF”) in which cash flows anticipated over several periods, plus a terminal
value at the end of that time horizon, are discounted to their present value using an appropriate expected discount rate. The
discount rate used for cash flows reflects capital market conditions and the specific risks associated with the business. This
valuation approach is considered a Level 3 fair value measurement. If actual results, market and economic conditions,
including interest rates, and other factors are not consistent with management’s estimates and assumptions used in this
calculation, the Company may be exposed to additional impairment losses.
The CEC Combination resulted in a loss of $6.5 million, which was recorded in “Loss from formation of equity
method investment” in the accompanying consolidated statements of operations for the year ended December 31, 2017.
The Company incurred working capital adjustments, funding for certain post-closing commitments, and transaction fees,
of which $3.3 million and $1.0 million was unpaid and recorded in “Accrued liabilities” in the accompanying consolidated
balance sheets as of December 31, 2018 and 2019, respectively. Included in this loss amount is goodwill of $3.6 million
that was allocated to the disposed assets based on the relative fair values of those assets and the portion of the reporting
unit that was retained. Prior to the CEC Combination, CEC had a pre-tax loss of $45.1 million for fiscal year 2017.
Subsequent to December 29, 2017, the Company recorded an increase of $1.2 million in anticipated relocation
expenses under the investment agreement in “Accrued liabilities” in the accompanying consolidated balance sheet as of
December 31, 2018 and in “Loss from formation of equity method investment” in the accompanying consolidated
statements of operations for the year ended December 31, 2018. The Company recorded income (loss) from this investment
of $(2.9) million and $0.0 million for the years ended December 31, 2018 and 2019, respectively. The Company had an
investment balance in SAFE&CEC S.r.l. of $23.4 million and $23.7 million as of December 31, 2018 and 2019,
respectively.
The Company determined that the CEC Combination did not meet the definition of a discontinued operation because
the disposal did not represent a strategic shift that will have a major effect on the Company’s operations and financial
results.
Note 5 —Investments in Other Entities and Noncontrolling Interest in a Subsidiary
SAFE&CEC S.r.l.
On December 29, 2017, the Company obtained a 49% ownership interest in SAFE&CEC S.r.l. See Note 4 for more
information.
76
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Summarized financial information for SAFE&CEC S.r.l. is as follows (in thousands):
Revenue
Gross profit
Operating income (loss)
Net income (loss)
Current assets
Non-current assets
Total assets
Current liabilities
Non-current liabilities
Total liabilities
MCEP
Year Ended December 31,
2019
2018
80,886
68,373 $
20,525
20,124 $
1,207
(4,881) $
93
(5,499) $
As of December 31,
2018
42,568 $
48,629
91,197 $
2019
56,765
56,153
112,918
$
$
$
$
$
$
$
36,177 $
6,955
$
43,132 $
51,911
11,952
63,863
On September 16, 2014, the Company formed a joint venture with Mansfield Ventures LLC (“Mansfield Ventures”)
called Mansfield Clean Energy Partners LLC (“MCEP”), which is designed to provide natural gas fueling solutions to bulk
fuel haulers in the United States. The Company and Mansfield Ventures each have a 50% ownership interest in MCEP.
The Company accounts for its interest in MCEP using the equity method of accounting because the Company does not
control but has the ability to exercise significant influence over MCEP’s operations. The Company recorded income (loss)
from this investment of $(0.1) million, $0.2 million and $(0.1) million for the years ended December 31, 2017, 2018, and
2019, respectively. The Company had an investment balance in MCEP of $1.7 million and $1.6 million as of December 31,
2018 and 2019, respectively.
NG Advantage
On October 14, 2014, the Company entered into a Common Unit Purchase Agreement (“UPA”) with NG Advantage
for a 53.3% controlling interest in NG Advantage. NG Advantage is engaged in the business of transporting CNG in high-
capacity trailers to industrial and institutional energy users, such as hospitals, food processors, manufacturers and paper
mills that do not have direct access to natural gas pipelines.
On July 14, 2017, the Company contributed to NG Advantage all of its right, title and interest in and to a CNG fueling
station located in Milton, Vermont. The Company purchased this CNG fueling station from NG Advantage in
October 2014 in connection with the UPA, and at that time, the Company entered into a lease agreement with NG
Advantage to lease the station back to NG Advantage. This lease agreement was terminated contemporaneously with the
contribution of the station to NG Advantage in July 2017. As consideration for the contribution, NG Advantage issued to
the Company Series A Preferred Units with an aggregate value of $7.5 million. The Series A Preferred Units provide for
an accrued return upon a liquidation event with respect to NG Advantage and will convert into common units of NG
Advantage if and when it completes a future equity financing that satisfies certain specified conditions; however, the
Series A Preferred Units do not, in themselves, increase the Company’s controlling interest in NG Advantage. As a result,
immediately following the contribution, the Company’s controlling interest in NG Advantage remained at 53.3%.
NG Advantage has entered into an arrangement with BP for the supply, sale and reservation of a specified volume of
CNG transportation capacity until March 2022. On February 28, 2018, the Company entered into a guaranty agreement
with NG Advantage and BP pursuant to which the Company guarantees NG Advantage’s payment obligations to BP in
the event of default by NG Advantage under the supply arrangement, in an amount up to an aggregate of $30.0 million
77
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
plus related fees. This guaranty is in effect until thirty days following the Company’s notice to BP of its termination. As
initial consideration for the guaranty agreement, NG Advantage issued to the Company 19,660 common units, which
increased the Company’s controlling interest in NG Advantage from 53.3% to 53.5%.
On October 1, 2018, the Company purchased 1,000,001 common units from NG Advantage for an aggregate cash
purchase price of $5.0 million. This purchase increased Clean Energy’s controlling interest in NG Advantage from 53.5%
to 61.7%.
In each month from November 2018 through February 2019, the Company was issued 100,000 additional common
units of NG Advantage, for a total of 400,000 common units, pursuant to the guaranty agreement entered in February 2018.
The issuance of 400,000 additional common units increased the Company’s controlling interest in NG Advantage to 63.0%
and 64.6% as of December 31, 2018 and 2019, respectively.
On February 15, 2019, NG Advantage and the Company entered into a transaction pursuant to which the Company
agreed to lend to NG Advantage up to $5.0 million in accordance with the terms of a delayed draw convertible promissory
note (the “2019 Note”). NG Advantage simultaneously drew $2.5 million under the 2019 Note, and on April 15, 2019, NG
Advantage drew the remaining $2.5 million under the 2019 Note. As discussed below, on June 28, 2019, all unpaid
principal and accrued interest under the 2019 Note was subsumed within the 2019 Convertible Note (as defined below).
On May 17, 2019, the Company agreed to lend to NG Advantage up to $0.5 million in accordance with the terms of
a promissory note (the “2019 Bridge Loan”). On June 11, 2019, NG Advantage drew $0.1 million under the 2019 Bridge
Loan. As discussed below, on June 28, 2019, all unpaid principal and accrued interest under the 2019 Bridge Loan was
subsumed within the 2019 Convertible Note.
On June 28, 2019, the Company agreed to lend to NG Advantage up to $15.2 million in accordance with the terms of
a delayed draw convertible promissory note (the “June 2019 Convertible Note”). NG Advantage simultaneously drew $3.5
million under the June 2019 Convertible Note. The outstanding principal and accrued interest under the 2019 Note and
2019 Bridge Loan were incorporated into the June 2019 Convertible Note, which resulted in the cancellation of the 2019
Note and 2019 Bridge Loan. In connection with the June 2019 Convertible Note, NG Advantage issued to the Company a
warrant to purchase 86,879 common units. During the period of July 1, 2019 through November 26, 2019, NG Advantage
drew an additional $7.4 million under the June 2019 Convertible Note.
On November 27, 2019, the Company agreed to lend to NG Advantage up to $26.7 million in accordance with the
terms of a delayed draw convertible promissory note (the “November 2019 Convertible Note”). NG Advantage
simultaneously drew $3.4 million under the November 2019 Convertible Note. The outstanding principal and accrued
interest under the June 2019 Convertible Note were incorporated into the November 2019 Convertible Note, which
resulted in the cancellation of the June 2019 Convertible Note. All outstanding principal under the November 2019
Convertible Note bore interest at a rate of 12.0% per annum, and all unpaid principal and accrued interest under the
November 2019 Convertible Note was due on the earlier of December 31, 2019, subject to extension at the Company's
discretion, or the occurrence of an event of default (subject to notice requirements and cure periods in certain
circumstances). In connection with the November 2019 Convertible Note, NG Advantage issued to the Company a warrant
to purchase 2,000,000 common units. In December 2019, NG Advantage drew an additional $6.6 million under the
November 2019 Convertible Note. As of December 31, 2019, NG Advantage had an outstanding balance of $26.7 million,
plus accrued and unpaid interest, under the November 2019 Convertible Note. This intercompany transaction has been
eliminated in consolidation. See Note 23 —Subsequent Events for additional information about the November 2019
Convertible Note.
The Company recorded a loss attributable to the noncontrolling interest in NG Advantage of $2.2 million, $5.4 million
and $7.2 million for the years ended December 31, 2017, 2018, and 2019, respectively. The noncontrolling interest was
$17.0 million and $9.6 million as of December 31, 2018 and 2019, respectively.
78
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Note 6 —Cash, Cash Equivalents and Restricted Cash
Cash, cash equivalents and restricted cash as of December 31, 2018 and 2019 consisted of the following (in
thousands):
Current assets:
Cash and cash equivalents
Restricted cash - standby letters of credit
Restricted cash - held in escrow
Total cash, cash equivalents and current portion of restricted cash
Long-term assets:
Restricted cash - standby letters of credit
Total long-term portion of restricted cash
2018
2019
29,844 $
30
750
30,624 $
49,207
15
—
49,222
4,000 $
4,000 $
4,000
4,000
$
$
$
$
Total cash, cash equivalents and restricted cash
$
34,624 $
53,222
The Company considers all highly liquid investments with maturities of three months or less on the date of acquisition
to be cash equivalents.
The Company places its cash and cash equivalents with high credit quality financial institutions. At times, such
investments may be in excess of the Federal Deposit Insurance Corporation (“FDIC”) and Canadian Deposit Insurance
Corporation (“CDIC”) limits. Financial instruments that potentially subject the Company to concentrations of credit risk
consist principally of cash deposits. The amounts in excess of FDIC and CDIC limits were approximately $28.5 million
and $47.9 million as of December 31, 2018 and 2019, respectively.
The Company classifies restricted cash as short-term and a current asset if the cash is expected to be used in operations
within a year or to acquire a current asset. Otherwise, the restricted cash is classified as long-term. Short-term restricted
cash consisted of standby letters of credit renewed annually. Long-term restricted cash consisted of a standby letter of
credit.
Note 7 — Short-Term Investments
Short-term investments include available-for-sale debt securities and certificates of deposit. Available-for-sale debt
securities are carried at fair value, inclusive of unrealized gains and losses. Unrealized gains and losses on available for
sale debt securities are recognized in other comprehensive income (loss), net of applicable income taxes. Gains or losses
on sales of available-for-sale debt securities are recognized on the specific identification basis.
The Company reviews available-for-sale debt securities for 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, 2019, the Company believes the carrying values for its available-
for-sale debt securities are properly recorded.
79
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Short-term investments as of December 31, 2018 consisted of the following (in thousands):
Municipal bonds and notes
Zero coupon bonds
Corporate bonds
Certificates of deposit
Total short-term investments
Amortized
Cost
$
$
9,210 $
29,823
26,175
507
65,715 $
Gross
Unrealized
Losses
Estimated
Fair Value
(19) $
(28)
(22)
—
(69) $
9,191
29,795
26,153
507
65,646
Short-term investments as of December 31, 2019 consisted of the following (in thousands):
Municipal bonds and notes
Zero coupon bonds
Corporate bonds
Certificates of deposit
Total short-term investments
Amortized
Cost
$
$
2,986 $
33,919
19,509
518
56,932 $
Gross
Unrealized
Losses
Estimated
Fair Value
— $
—
(3)
—
(3) $
2,986
33,919
19,506
518
56,929
Note 8 - Derivative Instruments and Hedging Activities
In October 2018, the Company executed two commodity swap contracts with Total Gas & Power North America, an
affiliate of TOTAL and THUSA (as defined in Notes 13 and 14), for a total of five million diesel gallons annually from
April 1, 2019 to June 30, 2024. These commodity swap contracts are used to manage diesel price fluctuation risks related
to the natural gas fuel supply commitments the Company makes in its fueling agreements with fleet operators that
participate in the Zero Now truck financing program. These contracts are not designated as accounting hedges and as a
result, changes in the fair value of these derivative instruments are recognized in "Product revenue" in the accompanying
consolidated statements of operations.
During 2019, the Company entered into fueling agreements with fleet operators under the Zero Now truck financing
program. The fueling agreements contain a pricing feature indexed to diesel, which the Company determined to be
embedded derivatives and recorded at fair value at the time of execution, with the changes in fair value of the embedded
derivatives recognized as earnings in "Product revenue" in the accompanying consolidated statements of operations.
Derivatives as of December 31, 2018 consisted of the following (in thousands):
Assets:
Commodity swaps:
Current portion of derivative assets, related party
Long-term portion of derivative assets, related party
Total derivative assets
$
$
1,508 $
8,824
10,332 $
— $
—
— $
1,508
8,824
10,332
Gross Amounts
Recognized
Gross Amounts
Offset
Net Amount
Presented
80
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Derivatives and embedded derivatives as of as of December 31, 2019 consisted of the following (in thousands):
Assets:
Commodity swaps:
Long-term portion of derivative assets, related party
$
3,270 $
— $
3,270
Gross Amounts
Recognized
Gross Amounts
Offset
Net Amount
Presented
Fueling agreements:
Prepaid expenses and other current assets
Notes receivable and other long-term assets, net
Total derivative assets
Liabilities:
Commodity swaps:
232
491
3,993 $
—
—
— $
232
491
3,993
$
Current portion of derivative liabilities, related party
$
164 $
— $
Fueling agreements:
Accrued liabilities
Other long-term liabilities
Total derivative liabilities
42
39
$
245 $
—
—
— $
164
42
39
245
As of December 31, 2018 and 2019, the Company had a total volume on open commodity swap contracts of 25.0
million and 21.9 million diesel gallons at a weighted-average price per gallon of approximately $3.18 and $2.30,
respectively.
The following table reflects the weighted-average price of open commodity swap contracts as of December 31, 2018
and 2019, by year with associated volumes:
December 31, 2018
December 31, 2019
Year
2019
2020
2021
2022
2023
2024
Volumes
(Diesel Gallons)
Weighted -Average Price per
Diesel Gallon
Volumes
(Diesel Gallons)
Weighted -average Price per
Diesel Gallon
3,125,000 $
5,000,000 $
5,000,000 $
5,000,000 $
5,000,000 $
1,875,000 $
3.18
3.18
3.18
3.18
3.18
3.18
— $
4,986,000 $
5,000,000 $
5,000,000 $
5,000,000 $
1,870,000 $
—
2.37
2.34
2.34
2.34
1.76
Note 9 —Fair Value Measurements
The Company follows the authoritative guidance for fair value measurements with respect to assets and liabilities that
are measured at fair value on a recurring basis and non-recurring basis. Under the standard, fair value is defined as the exit
price, or the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between
market participants, as of the measurement date. The standard also establishes a hierarchy for inputs used in measuring
fair value that maximizes the use of observable inputs and minimizes the use of unobservable inputs by requiring that the
most observable inputs be used when available. Observable inputs are inputs 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,
81
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
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.
Assets and Liabilities Measured at Fair Value on a Recurring Basis
The Company’s available-for-sale debt securities and certificate of deposits are classified within Level 2 because they
are valued using the most recent quoted prices for identical assets in markets that are not active and quoted prices for
similar assets in active markets.
The Company used the income approach to value its outstanding commodity swap contracts and embedded derivatives
in its fueling agreements under the Zero Now truck financing program (see Note 8). Under the income approach, the
Company used a discounted cash flow (“DCF”) model in which cash flows anticipated over the term of the contracts are
discounted to their present value using an expected discount rate. The discount rate used for cash flows reflects the specific
risks in spot and forward rates and credit valuation adjustments. This valuation approach is considered a Level 3 fair value
measurement. The significant unobservable inputs used in the fair value measurement of the Company’s derivative
instruments are Ultra-Low Sulfur Diesel (“ULSD”) forward prices and differentials from ULSD to Petroleum
Administration for Defense District (“PADD”) regions. Significant increases (decreases) in any of those inputs in isolation
would result in a significantly lower (higher) fair value measurement. Generally, a change in the ULSD forward prices is
accompanied by a directionally opposite but less extreme change in the ULSD-PADD differential.
The Company estimated the fair value of its outstanding commodity swap contracts based on the following inputs as
of December 31, 2018 and 2019:
Significant Unobservable Inputs
Input Range
Weighted Average
Input Range
Weighted Average
ULSD Gulf Coast Forward Curve
Historical Differential to PADD 3 Diesel
Historical Differential to PADD 5 Diesel
$1.71 - $1.79 $
$0.76 - $1.16 $
$1.22 - $2.12 $
1.75
0.89
1.55
$1.76 - $1.88 $
$0.79 - $1.16 $
$1.32 - $2.30 $
1.81
0.91
1.78
December 31, 2018
December 31, 2019
The Company estimated the fair value of embedded derivatives in its fueling agreements under the Zero Now truck
financing program based on the following inputs as of December 31, 2019:
Significant Unobservable Inputs
ULSD Gulf Coast Forward Curve
Historical Differential to PADD 5 Diesel
December 31, 2019
Input Range
$1.76 - $1.88
$1.32 - $2.30
Weighted Average
$
$
1.81
1.78
The Company’s liability-classified warrants (or "derivative warrants"), which were all issued by NG Advantage, are
classified within Level 3 because the Company uses the Black-Scholes option pricing model to estimate the fair value
based on inputs that are not observable in any market.
There were no transfers of assets between Level 1, Level 2, or Level 3 of the fair value hierarchy as of December 31,
2018 or 2019.
82
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (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, 2018 and 2019 (in thousands):
Assets:
Available-for-sale securities (1):
Municipal bonds and notes
Zero coupon bonds
Corporate bonds
Certificates of deposit (1)
Commodity swap contracts (2)
Embedded derivatives (3)
Liabilities:
Warrants (4)
Assets:
Available-for-sale securities (1):
Municipal bonds and notes
Zero coupon bonds
Corporate bonds
Certificates of deposit (1)
Commodity swap contracts (2)
Embedded derivatives (3)
Liabilities:
Commodity swap contracts (2)
Embedded derivatives (3)
Warrants (4)
December 31, 2018 Level 1
Level 2
Level 3
$
9,191 $
29,795
26,153
507
10,332
—
— $
—
—
—
—
—
9,191 $
29,795
26,153
507
—
—
—
—
—
—
10,332
—
$
1,079 $
— $
— $
1,079
December 31, 2019 Level 1
Level 2
Level 3
$
$
2,986 $
33,919
19,506
518
3,270
723
— $
—
—
—
—
—
2,986 $
33,919
19,506
518
—
—
—
—
—
—
3,270
723
164 $
81
40
— $
—
—
— $
—
—
164
81
40
(1)
Included in “Short-term investments” in the accompanying consolidated balance sheets. See Note 7 for more information.
(2)
Included in “Derivative assets, related party” and “Long-term portion of derivative assets, related party” as of December 31, 2018, and “Derivative
liabilities, related party” and “Long-term portion of derivative assets, related party” as of December 31, 2019, in the accompanying consolidated
balance sheets. See Note 8 for more information.
(3)
Included in "Prepaid expenses and other current assets", "Notes receivable and other long-term assets, net", “Accrued liabilities” and “Other long-
term liabilities” in the accompanying consolidated balance sheets. See Note 8 for more information.
(4)
Included in "Other long-term liabilities" as of December 31, 2018, and “Accrued liabilities” as of December 31, 2019 in the accompanying
consolidated balance sheets.
83
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The following table provides a reconciliation of the beginning and ending balances of items measured at fair value on
a recurring basis as shown in the tables above that used significant unobservable inputs (Level 3), as well as the change in
unrealized gains or losses for the periods included in earnings (in thousands):
Balance as of December 31, 2017
Total gain (loss)
Balance as of December 31, 2018
Balance as of December 31, 2018
Settlements, net
Total gain (loss)
Balance as of December 31, 2019
Change in unrealized gain (loss) for the year ended
December 31, 2018 included in earnings
Change in unrealized gain (loss) for the year ended
December 31, 2019 included in earnings
Other Financial Assets and Liabilities
Assets:
Embedded
Assets:
Commodity
Liabilities:
Commodity
Liabilities:
Embedded Liabilities:
Swap Contracts Derivatives Swap Contracts Derivatives Warrants
(536)
$
— $
—
(543)
— $ (1,079)
10,332
10,332 $
— $
—
— $
—
—
—
— $
$
$
$
$
$
10,332 $
667
(7,729)
3,270 $
— $
—
723
723 $
—
—
(164)
(164)
$
$
— $ (1,079)
—
—
1,039
(81)
(40)
(81) $
$
10,332 $
— $
—
$
— $
(543)
$
(7,062) $
723 $
(164)
$
(81) $
1,039
The carrying amounts of the Company’s cash, cash equivalents and restricted cash, receivables and payables
approximate fair value due to the short-term nature of those instruments. The carrying amounts of the Company’s debt
instruments approximated their respective fair values as of December 31, 2018 and 2019. The fair values of these debt
instruments were estimated using a discounted cash flow analysis based on interest rates offered on loans with similar
terms to borrowers of similar credit quality, which are Level 3 inputs. See Note 13 for more information about the
Company’s debt instruments.
Note 10 —Other Receivables
Other receivables as of December 31, 2018 and 2019 consisted of the following (in thousands):
Loans to customers to finance vehicle purchases
Accrued customer billings
Fuel tax credits
Other
Total other receivables
2018
276 $
6,261
434
8,573
15,544 $
2019
653
6,124
69,585
8,536
84,898
$
$
84
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Note 11 —Land, Property and Equipment
Land, property and equipment, net as of December 31, 2018 and 2019 consisted of the following (in thousands):
Land
LNG liquefaction plants
Station equipment
Trailers
Other equipment
Construction in progress
Less accumulated depreciation
Total land, property and equipment, net
2018
3,681 $
94,633
319,119
75,901
97,268
73,485
664,087
(313,519)
350,568 $
2019
3,476
94,633
324,431
79,477
101,655
75,232
678,904
(354,992)
323,912
$
$
Included in "Land, property and equipment, net" are capitalized software costs of $29.3 million and $30.4 million as
of December 31, 2018 and 2019, respectively. Accumulated amortization of the capitalized software costs is $22.5 million
and $26.3 million as of December 31, 2018 and 2019, respectively.
The Company recorded amortization expense related to the capitalized software costs of $4.4 million, $3.7 million
and $3.9 million during the years ended December 31, 2017, 2018, and 2019, respectively.
As of December 31, 2018, and 2019, $4.6 million and $3.0 million, respectively, are included in "Accounts payable"
and "Accrued liabilities" in the accompanying consolidated balance sheets which amounts are related to purchases of
property and equipment. These amounts are excluded from the accompanying consolidated statements of cash flows as
they are non-cash investing activities.
Note 12 —Accrued Liabilities
Accrued liabilities as of December 31, 2018 and 2019 consisted of the following (in thousands):
Accrued alternative fuels incentives (1)
Accrued employee benefits
Accrued interest
Accrued gas and equipment purchases
Accrued property and other taxes
Accrued salaries and wages
Other (2)
Total accrued liabilities
2018
6,923 $
2,248
78
12,833
3,397
8,609
14,381
48,469 $
2019
27,839
2,276
220
11,383
3,732
9,105
13,142
67,697
$
$
(1)
Includes the amount of RINs, LCFS Credits and the amount of AFTC payable to third parties.
(2) The amounts as of December 31, 2018 and 2019 include lease termination fees and AROs related to the closure of certain fueling stations and
working capital adjustments (see Note 3 for more information), in addition to funding for certain commitments and transaction fees incurred as a
result of the CEC Combination (see Note 4 for more information). No individual item in “Other” exceeds 5% of total current liabilities.
85
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Note 13 —Debt
Debt obligations as of December 31, 2018 and 2019 consisted of the following (in thousands):
7.5% Notes
NG Advantage debt
Other debt
Total debt
Less amounts due within one year
Total long-term debt
7.5% Notes
NG Advantage debt
SG Facility
Other debt
Total debt
Less amounts due within one year
Total long-term debt
Principal Balances
December 31, 2018
Unamortized Debt
Financing Costs
Balance, Net of
Financing Costs
$
$
50,000 $
28,904
1,024
79,928
(4,811)
75,117 $
58 $
155
—
213
(99)
114 $
49,942
28,749
1,024
79,715
(4,712)
75,003
Principal Balances
December 31, 2019
Unamortized Debt
Financing Costs
Balance, Net of
Financing Costs
$
$
50,000 $
33,898
4,400
796
89,094
(56,097)
32,997 $
17 $
192
—
—
209
(84)
125 $
49,983
33,706
4,400
796
88,885
(56,013)
32,872
The following is a summary of the aggregate maturities of debt obligations for each of the yearly periods subsequent
to December 31, 2019 (in thousands):
7.5% Notes
NG Advantage debt
SG Facility
Other debt
Total
7.5% Notes
2021
2022
2023
2024
Thereafter
Total
2020
$ 50,000 $
5,857
—
240
— $
— $
— $
— $
6,300
—
215
$ 56,097 $ 6,340 $ 6,515 $ 11,500 $ 8,642 $
11,407
—
93
4,242
4,400
—
6,092
—
248
— $ 50,000
33,898
—
4,400
—
—
796
— $ 89,094
In June 2013, the Company issued notes (the “7.5% Notes”) to T. Boone Pickens and Green Energy Investment
Holdings, LLC (“GEIH”) in the amount of $150.0 million. The 7.5% Notes bear interest at the rate of 7.5% per annum
and are convertible at the option of the holder into shares of the Company’s common stock at a conversion price of $15.80
per share (the “7.5% Notes Conversion Price”). Upon written notice to the Company, each holder of a 7.5% Note has the
right to exchange all or any portion of the principal and accrued and unpaid interest under its 7.5% Notes for shares of the
Company’s common stock at the 7.5% Notes Conversion Price. Additionally, subject to certain restrictions, the Company
can force conversion of each 7.5% Note into shares of its common stock if such shares trade at a 40% premium to the
7.5% Notes Conversion Price for at least 20 trading days in any consecutive 30 trading day period.
The entire principal balance of each 7.5% Note is due and payable seven years following its original issuance and the
Company may repay each 7.5% Note at maturity in shares of its common stock (provided that the Company may not issue
more than 13,993,630 shares of its common stock to holders of 7.5% Notes) or cash. All of the shares issuable upon
conversion of the 7.5% Notes have been registered for resale by their holders pursuant to a registration statement that has
been filed with and declared effective by the Securities and Exchange Commission.
86
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The 7.5% Notes include customary events of default which, if any of them occurs, would permit or require the
principal of, and accrued interest on, the 7.5% Notes to become, or to be declared, due and payable. No events of default
under the 7.5% Notes had occurred as of December 31, 2019.
On August 27, 2013, GEIH transferred $5.0 million in principal amount of its 7.5% Notes to third parties.
On February 9, 2017, the Company purchased from Mr. Pickens his 7.5% Note due July 2018, having an outstanding
principal amount of $25.0 million, for a cash purchase price of $21.8 million. Upon such purchase, the applicable 7.5%
Notes were surrendered and canceled in full. The Company’s repurchase of this 7.5% Note resulted in a gain of $3.2
million for the year ended December 31, 2017.
On February 21, 2017, GEIH transferred $11.8 million in principal amount of its 7.5% Notes to third parties.
On November 17, 2017, Mr. Pickens transferred all remaining $40.0 million in principal amount of his 7.5% Notes to
a third party.
On June 29, 2018, and pursuant to the consent of the holders of the 7.5% Notes to the Company’s payments of amounts
owed thereunder before maturity, the Company paid to the holders, in cash, an aggregate of $25.0 million in principal
amount and $0.5 million in accrued and unpaid interest owed under all outstanding 7.5% Notes due July 2018. Upon such
payment, the purchased 7.5% Notes were canceled in full.
On December 4, 2018, the Company purchased from the holders, thereof all outstanding 7.5% Notes due July 2019,
having an aggregate outstanding principal amount of $50.0 million, for a cash purchase price of $50.5 million. Upon such
payment, the purchased 7.5% Notes were canceled in full.
As a result of the foregoing transactions, as of December 31, 2019, (i) GEIH held 7.5% Notes in an aggregate principal
amount of $32.9 million and (ii) other third parties held 7.5% Notes in an aggregate principal amount of $17.1 million, all
of which mature in June 2020.
Plains Credit Facility
On February 29, 2016, the Company entered into a Loan and Security Agreement (the “Plains LSA”) with Plains
Capital Bank (“Plains”), which, as amended on December 6, 2017, had a maturity date of September 30, 2019. Pursuant
to the Plains LSA, Plains agreed to lend the Company up to $50.0 million on a revolving basis from time to time (the
“Credit Facility”). There was no activity or borrowings under this Credit Facility during the years ended December 31,
2018 and 2019, and the Credit Facility matured and was canceled on September 30, 2019.
SG Credit Agreement
On January 2, 2019, the Company entered into a term credit agreement (the “Credit Agreement”) with Société
Générale, a company incorporated as a société anonyme under the laws of France (“SG”). The Credit Agreement provides
for a term loan facility (the “SG Facility”) pursuant to which the Company may obtain, subject to certain conditions, up to
$100.0 million of loans (“SG Loans”) in support of its Zero Now truck financing program. Under the Credit Agreement,
the Company is permitted to use the proceeds from the SG Loans solely to fund the incremental cost of trucks purchased
or financed under the Zero Now truck financing program and related fees and expenses incurred by the Company in
connection therewith. Interest on outstanding SG Loans accrues at a rate equal to LIBOR plus 1.30% per annum, and a
commitment fee on any unused portion of the SG Facility accrues at a rate equal to 0.39% per annum. Interest and
commitment fees are payable quarterly. The Company is required to make mandatory prepayments under the SG Facility
equal to any amounts the Company receives for complete or partial refunds of the incremental cost of trucks purchased or
financed under the Zero Now program, and the Company is generally permitted to make complete or partial voluntary
prepayments under the SG Facility with prior written notice to SG but without premium or penalty. The Credit Agreement
87
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
includes certain representations, warranties and covenants by the Company and also provides for customary events of
default which, if any of them occurs, would permit or require, among other things, the principal of and accrued interest on
the Loans to become or to be declared due and payable. Events of default under the Credit Agreement include, among
others, nonpayment of principal and interest when due; violation of covenants; any default by the Company (whether or
not resulting in acceleration) under any other agreement for borrowed money in excess of $20.0 million; voluntary or
involuntary bankruptcy; repudiation or assignment of the Guaranty by THUSA; or a change of control of the Company.
The Credit Agreement does not include financial covenants, and the Company has not provided SG with any security
for its obligations under the Credit Agreement. As described below, THUSA has entered into the Guaranty to guarantee
the Company’s payment obligations to SG under the Credit Agreement. As of December 31, 2019, the Company had $4.4
million outstanding on the SG Facility and no events of defaults had occurred.
TOTAL Credit Support Agreement
On January 2, 2019, the Company entered into a credit support agreement (“CSA”) with Total Holdings USA Inc.
(“THUSA”), a wholly owned subsidiary of TOTAL (as defined in Note 14). Under the CSA, THUSA agreed to enter into
a guaranty agreement (“Guaranty”) pursuant to which it has guaranteed the Company’s obligation to repay to SG up to
$100.0 million in SG Loans and interest thereon in accordance with the Credit Agreement. In consideration for the
commitments of THUSA under the CSA, the Company is required to pay THUSA a quarterly guaranty fee at a rate per
quarter equal to 2.5% of the average aggregate Loan amount for the preceding calendar quarter.
Following any payment by THUSA to SG under the Guaranty, the Company would be obligated to immediately pay
to THUSA the full amount of such payment plus interest on such amount at a rate equal to LIBOR plus 1.0%. In addition,
the Company would be obligated to pay and reimburse THUSA for all reasonable out-of-pocket expenses it incurs in the
performance of its services under the CSA, including all reasonable out-of-pocket attorneys’ fees and expenses incurred
in connection with the payment to SG under the Guaranty or any enforcement or attempt to enforce any of the Company‘s
obligations under the CSA. The CSA includes customary representations and warranties and affirmative and negative
covenants by the Company. In addition, upon the occurrence of a “Trigger Event” and during its continuation, THUSA
may, among other things: elect not to guarantee additional Loans; declare all or any portion of the outstanding amounts
the Company owes THUSA under the CSA to be due and payable; and exercise all other rights it may have under applicable
law. Each of the following events constitutes a Trigger Event: the Company defaults with respect to any payment obligation
under the CSA; any representation or warranty made by the Company in the CSA was false, incorrect, incomplete or
misleading in any material respect when made; the Company fails to observe or perform any material covenant, obligation,
condition or agreement in the CSA; or the Company defaults in the observance or performance of any agreement, term or
condition contained in any other agreement with THUSA or an affiliate of THUSA.
As security for the Company’s obligations under the CSA, on January 2, 2019, the Company entered into a pledge
and security agreement with THUSA and delivered a collateral assignment of contracts to THUSA, pursuant to which the
Company collaterally assigned to THUSA all fueling agreements it enters into with participants in the Zero Now truck
financing program. In addition, on January 2, 2019, the Company entered into a lockbox agreement with THUSA and
Plains, under which the Company granted THUSA a security interest in the cash flow generated by the fueling agreements
the Company enters into with participants in the Zero Now truck financing program.
Until the occurrence of a Trigger Event or Fundamental Trigger Event (as described below) under the CSA, the
Company has the freedom to operate in the normal course and there are no restrictions on the flow of funds in and out of
the lockbox account established pursuant to the lockbox agreement. Upon the occurrence of a Trigger Event under the
CSA, all funds in the lockbox account will be: first, used to make scheduled debt repayments under the Credit Agreement;
and second, released to the Company. Further, upon the occurrence of a “Fundamental Trigger Event” under the CSA and
during its continuation, in addition to exercising any of the remedies available to THUSA upon the occurrence of a Trigger
Event as described above: all participants in the Zero Now program would pay amounts owed under their fueling
agreements with the Company directly into the lockbox account; under a “sweep” mechanism, all cash in the lockbox
account would be used to prepay all outstanding Loans under the Credit Agreement; no other disbursements from the
88
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
lockbox account could be made without THUSA’s consent; and THUSA would retain dominion over the lockbox account
and the funds in the account would remain as security for the Company’s payment and reimbursement obligations under
the CSA. Each of the following events constitutes a Fundamental Trigger Event: the Company defaults in the observance
or performance of any agreement, term or condition contained in the Credit Agreement that would constitute an event of
default thereunder, up to or beyond any grace period provided in such agreement, unless waived by SG; the Company
defaults in the observance or performance of any agreement, term or condition contained in any evidence of indebtedness
other than the Credit Agreement, and the effect of such default is to cause, or permit the holders of such indebtedness to
cause, acceleration of indebtedness in an aggregate amount for all such collective defaults of $20.0 million or more;
voluntary and involuntary bankruptcy and insolvency events; and the occurrence of a change of control of the Company.
The CSA will terminate following the later of: the payment in full of all of the Company’s obligations under the CSA;
and the termination or expiration of the Guaranty following the maturity date of the last outstanding Loan or December 31,
2023, whichever is earlier.
NG Advantage Debt
On May 12, 2016 and January 24, 2017, respectively, NG Advantage entered into a Loan and Security Agreement
(the “Commerce LSA”) with Commerce Bank & Trust Company (“Commerce”), pursuant to which Commerce agreed to
lend NG Advantage $6.3 million and $6.2 million, respectively. The proceeds were primarily used to fund the purchases
of CNG trailers and equipment. Interest and principal for both loans are payable monthly in 84 equal monthly installments
at an annual rate of 4.41% and 5.0%, respectively. As collateral security for the prompt payment in full when due of NG
Advantage’s obligations to Commerce under the Commerce LSA, NG Advantage pledged to and granted Commerce a
security interest in all of its right, title and interest in the CNG trailers and equipment purchased with the proceeds received
under the Commerce LSA.
On November 30, 2016, NG Advantage entered into a Loan and Security Agreement (the “Wintrust LSA”) with
Wintrust Commercial Finance (“Wintrust”), pursuant to which Wintrust agreed to lend NG Advantage $4.7 million. The
proceeds were primarily used to fund the purchases of CNG trailers and equipment. Interest and principal is payable
monthly in 72 equal monthly installments at an annual rate of 5.17%. As collateral security for the prompt payment in full
when due of NG Advantage’s obligations to Wintrust under the Wintrust LSA, NG Advantage pledged to and granted
Wintrust a security interest in all of its right, title and interest in the CNG trailers and equipment purchased with the
proceeds received under the Wintrust LSA.
Financing Obligations
NG Advantage has entered into sale and leaseback transactions with various lessors as described below. In each
instance, the sale and leaseback transaction does not qualify for sale-leaseback accounting because of NG Advantage’s
continuing involvement with the buyer-lessor due to a fixed price repurchase option. As a result, the transactions are
recorded under the financing method, in which the assets remain on the accompanying consolidated balance sheets and
the proceeds from the transactions are recorded as financing liabilities.
On December 18, 2017, NG Advantage entered into a sale-leaseback arrangement through a Master Lease Agreement
(the “BoA MLA”) with Bank of America Leasing & Capital, LLC (“BoA”). Pursuant to the BoA MLA, NG Advantage
received $2.1 million in cash for CNG trailers and simultaneously leased them back from BoA for five years commencing
January 1, 2018 with interest and principal payable in 60 equal monthly installments at an annual rate of 4.86%.
On March 1, 2018, NG Advantage entered into a sale-leaseback arrangement through a Master Lease Agreement (the
“First National MLA”) with First National Capital, LLC (“First National”). Pursuant to the First National MLA, NG
Advantage received $6.3 million in cash, net of fees and the first month’s lease payment for CNG trailers and
simultaneously leased them back from First National for six years commencing March 1, 2018 with interest and principal
payable in 72 equal monthly installments at an annual rate of 9.28%.
89
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
On December 20, 2018 (the “Closing Date”), NG Advantage entered into a purchase agreement to sell a compression
station for a purchase price of $7.0 million to an entity whose member owners were noncontrolling interest member owners
of NG Advantage. On the Closing Date and immediately following the consummation of the sale of the compression
station, NG Advantage entered into a lease agreement with the buyer of the station (the “Lease”) pursuant to which the
station was leased back to NG Advantage for a term of five years with monthly rent payments equal to $0.1 million at an
annual rate of 12.0%. Of the purchase price, NG Advantage received $4.7 million in cash, net of fees, the first month’s
lease payment, and the repayment of a $2.0 million promissory note from one of the member owners of the buyer, which
was issued on November 19, 2018.
On January 17, 2019, NG Advantage entered into a sale-leaseback arrangement through a Master Lease Agreement
(the “Nations MLA”) with Nations Fund I, LLC (“Nations”). Pursuant to the Nations MLA, NG Advantage received $3.4
million in cash, net of the first month’s lease payment, for CNG trailers and simultaneously leased them back from Nations
for four years commencing February 1, 2019 with interest and principal payable in 48 equal monthly installments at an
annual rate of 9.18%.
In October 2019, NG Advantage entered into a sale-leaseback agreement, pursuant to which it sold compression
equipment for a purchase price of $7.5 million and simultaneously leased it back for a term of five years with interest and
principal payable in equal monthly installments at an annual rate of 10.47%. Of the purchase price, NG Advantage received
$5.3 million in cash and $2.2 million is held as a security deposit.
Other Debt
The Company has other debt due at various dates through 2023 bearing interest at rates up to 5.02% and with a
weighted-average interest rate of 4.78% as of December 31, 2018 and 2019.
Note 14 —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, 2019, the Company was
authorized to issue 305,000,000 shares, of which 304,000,000 shares are designated common stock and 1,000,000 shares
are designated preferred stock.
Dividend Provisions
The Company did not declare or pay any dividends during the years ended December 31, 2017, 2018 or 2019.
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
At-The-Market Offering Program
On May 31, 2017, the Company terminated its equity distribution agreement (the “Sales Agreement”) with Citigroup
Global Markets Inc. (“Citigroup”), as sales agent and/or principal. The Sales Agreement was terminable at will upon
written notification by the Company with no penalty. Pursuant to the Sales Agreement, the Company was entitled to issue
and sell, from time to time through or to Citigroup, shares of its common stock having an aggregate offering price of up
to $200.0 million in an “at-the-market” offering program (the “ATM Program”). The ATM Program commenced on
90
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
November 11, 2015 when the Company and Citigroup entered into the original equity distribution agreement, which was
amended and restated on September 9, 2016 and again on December 21, 2016 prior to its termination.
The following table summarizes the activity under the ATM Program for the periods presented:
(in 000s, except share amounts)
Gross proceeds
Fees and issuance costs
Net proceeds
Shares issued
Total Private Placement
Year ended December 31,
2017
$
$
10,767
311
10,456
3,802,500
On May 9, 2018, the Company entered into a stock purchase agreement (the “Purchase Agreement”) with Total
Marketing Services, S.A. (“Total”), a wholly owned subsidiary of TOTAL S.A. (“TOTAL”). Pursuant to the Purchase
Agreement, the Company agreed to sell and issue, and Total agreed to purchase, up to 50,856,296 shares of the Company’s
common stock at a purchase price of $1.64 per share, all in a private placement (the “Total Private Placement”). The
purchase price per share was determined based on the volume-weighted average price for the Company’s common stock
between March 23, 2018 (the day on which discussions began between the Company and Total) and May 3, 2018 (the day
on which the Company agreed in principle with Total regarding the structure and basic terms of its investment). As of the
date of the Purchase Agreement, Total did not hold or otherwise beneficially own any shares of the Company’s common
stock, and Total has agreed, until the later of May 9, 2020 or such date when it ceases to hold more than 5.0% of the
Company’s common stock then outstanding, among other similar undertakings and subject to customary conditions and
exceptions, to not purchase shares of the Company’s common stock or otherwise pursue transactions that would result in
Total beneficially owning more than 30.0% of the Company’s equity securities without the approval of the Company’s
board of directors.
On June 13, 2018, the Company and Total closed the Total Private Placement, in which: (1) the Company issued to
Total all of the 50,856,296 shares of its common stock issuable under the Purchase Agreement, resulting in Total holding
approximately 25.0% of the outstanding shares of the Company’s common stock and the largest ownership position of the
Company as of September 30, 2018; (2) Total paid to the Company an aggregate of $83.4 million in gross proceeds, which
the Company has used and expects to continue to use for working capital and general corporate purposes, which may
include executing its business plans, pursuing opportunities for further growth, and retiring a portion of its outstanding
indebtedness; and (3) the Company and Total entered into a registration rights agreement, described below. In connection
with the issuance of common stock, the Company incurred transaction fees of $1.9 million.
Pursuant to the Purchase Agreement, the Company and Total also entered into a registration rights agreement on
June 13, 2018, upon the closing under the Purchase Agreement. Pursuant to the registration rights agreement, the Company
filed a registration statement with the SEC to cover the resale of the shares issued and sold under the Purchase Agreement,
which was declared effective on August 16, 2018, and is obligated to use its commercially reasonable efforts to maintain
the effectiveness of such registration statement until all such shares are sold or may be sold without restriction under
Rule 144 under the Securities Act of 1933, as amended. As of December 31, 2019, the Company was in compliance with
all of its registration covenants set forth in the registration rights agreement.
Other
As of December 31, 2019, a third-party and a related party held outstanding warrants, which expire in 2020 and 2025,
respectively, to purchase equity interests in NG Advantage. Such warrants allow the purchase of up to 765,106 NG
Advantage common units and are accounted for as liability-classified warrants. The fair value was $1.1 million and $0.0
million as of December 31, 2018 and 2019, respectively (see Note 9 for more information) and the gain (loss) from the
91
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
change in fair value was $0.0 million, $(0.5) million and $1.0 million for the years ended December 31, 2017, 2018, and
2019, respectively.
Stock-Based Compensation
The following table summarizes the compensation expense and related income tax benefit related to the Company’s
stock-based compensation arrangements recognized in the accompanying consolidated statements of operations during the
periods presented (in thousands):
Stock-based compensation expense, net of $0 tax in 2017, 2018 and 2019 (1)
$
Year Ended December 31,
2018
5,307 $
2017
8,423 $
2019
3,880
(1) $0.3 million of stock-based compensation expense for the year ended December 31, 2017 is recorded in “Asset impairments and other charges” in
the accompanying consolidated statements of operations and in “Asset impairments and other charges” in the accompanying consolidated
statements of cash flows. See Note 3 for more information.
Equity Incentive Plans
In December 2002, the Company adopted its 2002 Stock Option Plan (“2002 Plan”).
In December 2006, the Company adopted its 2006 Equity Incentive Plan (“2006 Plan”), which became 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, at which time unissued awards under the 2002 Plan
became available for grant under the 2006 Plan.
In May 2016, the Company adopted its 2016 Performance Incentive Plan (“2016 Plan”), which became effective on
May 26, 2016, the date of approval of the 2016 Plan by the Company’s stockholders. The 2006 Plan became unavailable
for new awards upon the effectiveness of the 2016 Plan. Unissued awards under the 2002 and 2006 Plans are not available
for future grant under the 2016 Plan. If any outstanding award under the 2002 Plan or 2006 Plan expires or is canceled,
the shares allocable to the unexercised portion of that award will be added to the share reserve under the 2016 Plan and
will be available for grant under the 2016 Plan. As of December 31, 2019, the Company had 2,054,993 shares available
for future grant under the 2016 Plan.
Stock Options
The Company has granted stock options to key employees that vest annually over the three years following the date
of grant at a rate of 34%, 33% and 33%, respectively, if the holder is in service to the Company at each vesting date. The
stock options granted have contractual terms of 10 years. The stock options are subject to the terms and conditions of the
2006 and 2016 Plans and a Notice of Grant of Stock Option and Stock Option Agreement.
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CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The following table summarizes the Company’s stock option activity for the year ended December 31, 2019:
Weighted
Average
Exercise
Price
Number of
Shares
Weighted
Average
Remaining
Contractual
Term
Aggregate
Intrinsic
Value
(in years) (in thousands)
Options outstanding as of December 31, 2018
Granted
Exercised
Forfeited or expired
Options outstanding as of December 31, 2019
Options exercisable as of December 31, 2019
Options vested and expected to vest as of December 31, 2019
8,699,677 $
2,183,691
(58,602)
(1,703,101)
9,121,665 $
6,246,982 $
9,121,665 $
8.06
2.19
1.79
10.07
6.32
8.31
6.32
5.82 $
4.52 $
5.82 $
1,909
812
1,909
As of December 31, 2019, there was $1.9 million of total unrecognized compensation cost related to unvested shares
underlying outstanding stock options. That cost is expected to be expensed over a remaining weighted average period of
1.45 years. The total fair value of shares vested during the year ended December 31, 2019 was $1.6 million.
The fair value of each stock option granted was estimated as of the date of grant using the Black-Scholes option
pricing model and using the following assumptions:
Dividend yield
Expected volatility
Risk-free interest rate
Expected life in years
2017
0.0%
63.61%
2.05%
6.0
Year Ended December 31,
2018
0.0%
70.2% to 74.6%
2.70% to 2.71%
6.0
2019
0.0%
57.3% to 61.5%
2.11% to 2.53%
6.0
The volatility amounts used were estimated based on the Company’s historical and implied volatility of its traded
options. The expected lives used were based on historical exercise periods and the Company’s anticipated exercise periods
for its outstanding stock options. The risk-free interest rates used were based on the U.S. Treasury yield curve for the
expected life of the stock options at the time of grant.
The weighted-average grant date fair values per share of stock options granted during the years ended December 31,
2017, 2018, and 2019, were $1.67, $0.88 and $1.28, respectively. The aggregate intrinsic value of options exercised during
the years ended December 31, 2018 and 2019 were $0.0 million and $0.1 million, respectively. There were no options
exercised during the year ended December 31, 2017. The Company recorded $2.2 million, $2.0 million and $2.2 million
of stock option expense during the years ended December 31, 2017, 2018, and 2019, respectively. The Company has not
recorded any tax benefit related to its stock option expense.
Service-Based Restricted Stock Units
The Company has granted service-based restricted stock units (“Service-Based RSUs”) to key employees that vest
annually over the three years following the date of grant at a rate of 34%, 33% and 33%, respectively, if the holder is in
service to the Company at each vesting date. The Service-Based RSUs are subject to the terms and conditions of the 2006
and 2016 Plans and a Notice of Grant of Restricted Stock Unit and Restricted Stock Unit Agreement.
93
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The following table summarizes the Company’s Service-Based RSU activity for the year ended December 31, 2019:
RSU outstanding as of December 31, 2018
Granted
Vested
Forfeited or expired
RSU outstanding and unvested as of December 31, 2019
Number of
Shares
2,279,601
—
(952,032)
(95,764)
1,231,805
$
$
Weighted
Average
Fair Value at
Grant Date
1.88
—
2.13
1.59
1.71
The weighted average grant-date fair value of RSUs granted during the years ended December 31, 2017 and 2018 was
$1.36. There were no RSUs granted during the year ended December 31, 2019.
As of December 31, 2019, there was $0.8 million of total unrecognized compensation cost related to unvested shares
underlying outstanding Service-Based RSUs. That cost is expected to be expensed over a remaining weighted-average
period of 0.91 years.
The Company recorded $5.9 million, $3.0 million and $1.5 million of expense during the years ended December 31,
2017, 2018, and 2019, respectively, related to the Service-Based RSUs. The Company has not recorded any tax benefit
related to its Service-Based RSU expense.
Employee Stock Purchase Plan
On May 7, 2013, the Company adopted an employee stock purchase plan (the “ESPP”), pursuant to which eligible
employees may purchase shares of the Company’s common stock at 85% of the fair market value of the common stock on
the last trading day of two consecutive, non-concurrent offering periods each year. The Company has reserved 2,500,000
shares of its common stock for issuance under the ESPP, and the first offering period under the ESPP commenced on
September 1, 2013.
The Company recorded $0.0 million of expense related to the ESPP during each of the years ended December 31,
2017, 2018, and 2019. The Company has not recorded any tax benefit related to its ESPP expense. As of December 31,
2019, the Company had issued an aggregate of 526,307 shares pursuant to the ESPP.
Note 15 —Income Taxes
The components of income (loss) before income taxes for the years ended December 31, 2017, 2018, and 2019 are as
follows (in thousands):
U.S.
Foreign
Total income (loss) before income taxes
94
2017
2018
2019
$ (44,535) $ (9,153) $ 14,981
(864)
$ (83,305) $ (8,842) $ 14,117
(38,770)
311
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The provision for income taxes for the years ended December 31, 2017, 2018, and 2019 consists of the following (in
thousands):
Current:
Federal
State
Foreign
Total current
Deferred:
Federal
State
Foreign
Total deferred
Total expense (benefit)
2017
2018
2019
$
31 $
— $
231
224
486
(978)
(184)
(1,238)
(2,400)
$ (1,914) $
341
—
341
—
—
—
—
341 $
—
116
4
120
293
445
—
738
858
The Company’s federal and state tax benefit from the utilization of net operating loss carryovers for the year ended
December 31, 2017 was $6.9 million and $1.5 million, respectively. Income tax expense (benefit) for the years ended
December 31, 2017, 2018, and 2019 differs from the “expected” amount computed using the federal income tax rate of
35% as of December 31, 2017 and 21% as of December 31, 2018 and 2019 as a result of the following (in thousands):
Computed expected tax (benefit)
Nondeductible expenses
Tax rate differential on foreign earnings
Joint ventures
Noncontrolling interest
Impact of federal income tax rate change
Tax credits
Other
Change in valuation allowance
Total tax expense (benefit)
2017
2018
$ (29,157) $ (1,857) $
13,420
11,860
—
—
59,729
(27)
2,376
(60,115)
$ (1,914) $
2019
2,964
3,087
245
(369)
4,114
—
(10,314)
665
466
858
5,674
(56)
947
1,133
—
(6,603)
985
118
341 $
On December 21, 2017, the TCJA was enacted. Among other things, the TCJA reduces the U.S. federal corporate tax
rate from 35 percent to 21 percent beginning on January 1, 2018, requires companies to pay a one-time transition tax on
certain previously unremitted earnings of non-U.S. subsidiaries, creates new taxes on certain foreign sourced earnings and
imposes additional limitations on certain deductions, including interest expense and net operating losses arising after 2017.
The Company has assessed the impact of the TCJA and is not subject to the one-time transition tax. The Company
remeasured certain deferred tax assets and liabilities and uncertain tax positions based on the rates at which they are
expected to reverse in the future, which is generally 21 percent under the TCJA. The decrease in the Company’s net
deferred tax assets as of December 31, 2017 was offset by a corresponding decrease in its valuation allowance.
The AFTC, which had previously expired on December 31, 2016, was reinstated on February 9, 2018 to apply to
vehicle fuel sales made from January 1, 2017 through December 31, 2017. As a result, all AFTC revenue for vehicle fuel
the Company sold in the 2017 calendar year was recognized and collected during the year ended December 31, 2018. On
December 20, 2019, AFTC was retroactively extended beginning January 1, 2018 through December 31, 2020. As a result,
all AFTC revenue for vehicle fuel the Company sold in the 2018 and 2019 calendar year was recognized during the year
ended December 31, 2019.
The Company recorded a federal tax benefit of $0.0 million, $6.1 million and $10.5 million related to the exclusion
of AFTC associated with 2017, 2018 and 2019 fuel sales in excess of its fuel tax obligation, respectively. These amounts
95
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
increased the Company’s deferred tax asset attributed to its federal net operating loss carryforwards and the Company’s
deferred tax asset valuation allowance.
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, 2018 and 2019 are as follows (in thousands):
2018
2019
Deferred tax assets:
Accrued expenses
Alternative minimum tax and general business credits
Stock option expense
Other
Loss carryforwards
Total deferred tax assets
Less valuation allowance
Net deferred tax assets
Deferred tax liabilities:
Commodity swap contracts
Depreciation and amortization
Goodwill
Investments in joint ventures and partnerships
Total deferred tax liabilities
Net deferred tax liabilities
$
5,254 $
6,801
11,210
1,998
106,957
132,220
(120,801)
11,419
4,899
6,651
9,254
1,456
107,722
129,982
(122,147)
7,835
(2,751)
(2,672)
(1,650)
(4,346)
(11,419)
$
— $
(998)
(911)
(1,910)
(4,754)
(8,573)
(738)
As of December 31, 2019, the Company had federal, state and foreign net operating loss carryforwards of
approximately $430.2 million, $298.3 million and $2.0 million, respectively. The Company’s federal, state and foreign
net operating loss carryforwards will, if not utilized, expire beginning in 2026, 2020 and 2030, respectively. The Company
also has federal tax credit carryforwards of $6.4 million that will expire beginning in 2026. 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, 2018 and 2019, the Company provided a valuation allowance of $120.8 million, and $122.1 million,
respectively, to reduce the net deferred tax assets due to uncertainty surrounding the realizability of these assets. The
decrease in the valuation allowance for the year ended December 31, 2018 of $0.0 million was primarily attributable to
the valuation allowance offsetting foreign income, partially offset by an increase in federal losses without benefit. The
increase in the valuation allowance for the year ended December 31, 2019 of $1.3 million was primarily attributable to an
increase in federal losses without benefit.
For the year ended December 31, 2019, the Company did not have any offshore earnings of certain non-U.S.
subsidiaries which are permanently reinvested outside the United States.
The Company does not recognize the impact of a tax position in its financial statements unless the position is more
likely than not to be sustained, based on the technical merits of the position. The Company has unrecognized tax benefits
of $41.5 million as of December 31, 2019 that, if recognized, would not result in a tax benefit since it would be fully offset
with a valuation allowance.
96
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The following is a tabular reconciliation of the total amounts of unrecognized tax benefits for the years ended
December 31, 2017, 2018, and 2019 (in thousands):
Unrecognized tax benefit—December 31, 2017
Gross increases—tax positions in current year
Unrecognized tax benefit—December 31, 2018
Gross increases—tax positions in current year
Unrecognized tax benefit—December 31, 2019
$
$
34,065
2,178
36,243
5,232
41,475
The increase in the Company’s unrecognized tax benefits in the years ended December 31, 2018 and 2019 is primarily
attributable to the portion of AFTC offset by the fuel tax the Company collected from its customers.
ASC 740, Income Taxes, 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. In addition to the unrecognized
tax benefits noted above, the Company accrued $0.0 million of interest expense as of December 31, 2018 and 2019. The
Company recognized interest expense related to uncertain tax positions of $0.1 million, $0.0 million and $0.0 million for
the years ended December 31, 2017, 2018, and 2019, respectively.
During the year ended December 31, 2018, the IRS concluded its examination of the Company’s U.S. federal income
tax returns for the year ended December 31, 2015 and did not propose any significant adjustments to the Company’s tax
positions.
The Company is subject to taxation in the United States and various states and foreign jurisdictions. The Company’s
tax years for 2015 through 2019 are subject to examination by various tax authorities. While the Company is no longer
subject to U.S. examination for years before 2016, and for state tax examinations for years before 2015, taxing authorities
can adjust the net operating losses that arose in earlier years if and when the net operating losses reduce future income. In
addition, the Company is required to indemnify SAFE&CEC S.r.l. for taxes that are imposed on CEC for pre-contribution
tax periods.
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 an 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 and penalties,
in light of changing facts and circumstances. The amount of penalties accrued is immaterial. 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 at the effective tax rate in the period of resolution. The Company does not expect a
significant increase or decrease in its uncertain tax positions within the next twelve months.
Note 16 —Commitments and Contingencies
Environmental Matters
The Company is subject to federal, state, local and foreign environmental laws and regulations. The Company does
not anticipate any expenditures to comply with such laws and regulations that would have a material 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.
97
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Litigation, Claims and Contingencies
The Company may become party to various legal actions that arise in the ordinary course of its business. The Company
is also subject to audit by tax and other authorities for varying periods in various federal, state, local and foreign
jurisdictions, and disputes may arise during the course of these audits. It is impossible to determine the ultimate liabilities
that the Company may incur resulting from any of these lawsuits, claims, proceedings, audits, commitments, contingencies
and related matters or the timing of these liabilities, if any. If these matters were to ultimately be resolved unfavorably, it
is possible that such an outcome could have a material adverse effect upon the Company’s consolidated financial position,
results of operations, or liquidity. The Company does not, however, anticipate such an outcome and it believes the ultimate
resolution of these matters will not have a material adverse effect on the Company’s consolidated financial position, results
of operations, or liquidity.
Long-Term Take-or-Pay Natural Gas Purchase Contracts
The Company has entered into two long-term CNG supply contracts to purchase CNG, on a take-or-pay basis, expiring
in December 2020 and June 2022, respectively. As of December 31, 2019, the fixed commitments under these contracts
totaled approximately $0.7 million, $0.2 million, and $0.1 million for the years ending December 31, 2020, 2021 and 2022,
respectively.
The Company has entered into quarterly fixed price natural gas purchase contracts with take-or-pay commitments
extending through June 2023. As of December 31, 2019, the fixed commitments under these contracts totaled
approximately $5.0 million, $1.2 million, $1.2 million, and $1.2 million for the years ending December 31, 2020, 2021,
2022, and 2023, respectively.
Long-Term Natural Gas Supply Contract
In June 2017, the Company’s subsidiary, NG Advantage, entered into an arrangement with BP for the supply, sale
and transportation of CNG over a five -year period starting in December 2018 and expiring March 2022. The arrangement
is customary and ordinary course and provides for the payment by the customer of a nonrefundable amount of $13.4
million to reserve a specified volume of CNG transportation capacity under the arrangement, which was collected during
the year ended December 31, 2017. As of December 31, 2019, the commitments for the specified volume under this
contract were estimated to be approximately $5.1 million, $12.5 million, and $11.1 million for the years ending
December 31, 2020, 2021 and 2022, respectively.
Note 17 —Leases
New Lease Accounting Standard (Topic 842)
On January 1, 2019, the Company adopted the new lease accounting standard (see Note 1 for more information on the
standard and the effect of the adoption) whereby leases are now classified as either operating leases or finance leases. The
Company’s operating leases are comprised of real estate for fueling stations, office spaces, warehouses, a LNG liquefaction
plant, and office equipment, and its finance leases are comprised of vehicles.
At the inception of a contract the Company assesses whether the contract is, or contains, a lease. The Company’s
assessment is based on: (1) whether the contract involves the use of a distinct identified asset, (2) whether the Company
obtains the right to substantially all the economic benefit from the use of the asset throughout the period, and (3) whether
the Company has the right to direct the use of the asset. The commencement date of the contract is the date the lessor
makes the underlying asset available for use by the lessee.
Right-of-use (“ROU”) assets represent the Company’s right to use an underlying asset during the lease term and lease
liabilities represent obligations to make lease payments arising from the lease. ROU assets and lease liabilities are
98
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
recognized at the commencement date based on the net present value of fixed lease payments over the lease term. ROU
assets also include any initial direct costs and advance lease payments made and exclude lease incentives. Lease liabilities
also include terminal purchase options when deemed reasonably certain to exercise. The Company’s lease term includes
options to extend when it is reasonably certain that it will exercise that option. The Company has elected not to recognize
ROU assets and lease liabilities for short-term leases that have a term of 12 months or less; the Company recognizes lease
expense for these leases on a straight-line basis over the lease term.
As most of the Company’s operating leases do not have an implicit rate that can be readily determined, the Company
uses its secured incremental borrowing rate for the same term as the underlying lease based on information available at
lease commencement. For finance leases, the Company uses the rate implicit in the lease.
The lease classification affects the expense recognition on the consolidated statements of operations. Operating lease
charges are recorded in “Cost of sales, exclusive of depreciation and amortization,” and “Selling, general and
administrative” expense. Finance lease charges are split, whereby depreciation on assets under finance leases is recorded
in “Depreciation and amortization” expense and an implied interest component is recorded in “Interest expense.” The
expense recognition for operating leases and finance leases is substantially consistent with legacy accounting.
The Company leased office space from the estate of T. Boone Pickens in Dallas, Texas. The Company incurred rent
expense of $0.1 million in each of the years ended December 31, 2017, 2018 and 2019. The lease expired in October 2019.
NG Advantage has provided residual value guarantees on leases of certain vehicles aggregating $1.4 million to the
lessors. NG Advantage expects to owe these amounts in full and therefore they have been included in the measurement of
the lease liabilities and ROU assets.
Certain of the Company’s real estate leases contain variable lease payments, including payments based on a change
in the index or gasoline gallon equivalents of natural gas dispensed at fueling stations. These variable lease payments
cannot be determined at the commencement of the lease, are not included in the ROU assets and lease liabilities, and are
recorded as a period expense when incurred.
Lessee Accounting
As of December 31, 2019, the Company’s finance and operating lease asset and liability balances were as follows (in
thousands):
Finance leases:
Land, property and equipment, gross
Accumulated depreciation
Land, property and equipment, net
Current portion of finance lease obligations
Long-term portion of finance lease obligations
Total finance lease liabilities
Operating leases:
Operating lease right-of-use assets (1)
Current portion of operating lease obligations
Long-term portion of operating lease obligations
Total operating lease liabilities
99
2019
5,177
(2,134)
3,043
615
2,715
3,330
28,627
3,359
26,206
29,565
$
$
$
$
$
$
$
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The Company’s operating lease ROU assets are comprised of the following (in thousands):
December 31, 2019
Real estate for fueling stations
LNG plant, office spaces and warehouses
Office equipment
Total operating lease right-of-use assets
$
$
Liabilities
Assets
17,978 $
10,624
25
28,627 $
17,978
11,562
25
29,565
The components of lease expense for finance and operating leases consisted of the following (in thousands):
Finance leases:
Depreciation on assets under finance leases
Interest on lease liabilities
Total finance leases expense
Operating leases:
Lease expense
Lease expense on short-term leases
Variable lease expense
Sublease income
Total operating leases expense
Year Ended
December 31, 2019
$
$
$
$
498
189
687
6,630
1,950
2,755
(206)
11,129
Supplemental information on finance and operating leases is as follows (dollars in thousands):
Operating cash outflows from finance leases
Operating cash outflows from operating leases
Financing cash outflows from finance leases
Assets obtained in exchange for new finance lease liabilities (1)
ROU assets obtained in exchange for operating lease liabilities (1)
Weighted-average remaining lease term - finance leases
Weighted-average remaining lease term - operating leases
Weighted-average discount rate - finance leases
Weighted-average discount rate - operating leases
Year Ended
December 31, 2019
189
5,350
1,667
$
$
$
$
$
519
31,861
December 31, 2019
4.49 years
11.10 years
5.09%
8.29%
(1) These amounts are excluded from the accompanying consolidated statements of cash flows as they are non-cash investing and financing activities.
100
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The following schedule represents the Company’s maturities of finance and operating lease liabilities as of
December 31, 2019 (in thousands):
Fiscal year:
2020
2021
2022
2023
2024
Thereafter
Total minimum lease payments
Less amount representing interest
Present value of lease liabilities
Lessor Accounting
Finance Leases Operating Leases
$
$
767 $
679
560
462
1,026
314
3,808
(478)
3,330 $
5,484
4,658
3,736
3,712
3,704
25,208
46,502
(16,937)
29,565
The Company leases fueling station equipment to customers that contain an option to extend and an end-of-term
purchase option. Receivables from these leases are accounted for as finance leases, specifically sales-type leases, and are
included in “Other receivables” and “Notes receivable and other long-term assets, net” in the accompanying consolidated
balance sheets.
The Company recognizes the net investment in the lease as the sum of the lease receivable and the unguaranteed
residual value, both of which are measured at the present value using the interest rate implicit in the lease.
During the year ended December 31, 2019, the Company recognized $0.1 million in “Interest income” on its lease
receivables.
The following schedule represents the Company’s maturities of lease receivables as of December 31, 2019 (in
thousands):
Fiscal year:
2020
2021
2022
2023
2024
Thereafter
Total minimum lease payments
Less amount representing interest
Present value of lease receivables
Legacy Lease Disclosures (Topic 840)
$
$
186
186
186
186
186
1,054
1,984
(935)
1,049
As required by the new lease accounting standard, certain legacy lease disclosures are provided below as of
December 31, 2018, prior to adoption of the new standard.
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. If a lease has a fixed and
101
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
determinable escalation clause, or periods of rent holidays, the difference between rental expense and rent paid is included
in “Accrued liabilities” and “Other long-term liabilities” in the accompanying condensed consolidated balance sheets.
The following schedule represents the Company’s future minimum lease obligations under all noncancelable
operating leases as of December 31, 2018 (in thousands):
Fiscal year:
2019
2020
2021
2022
2023
Thereafter
Total future minimum lease payments
Rent expense totaled $6.6 million for the year ended December 31, 2018.
Capital Lease Obligations and Receivables
$
$
6,340
4,332
3,311
2,409
2,300
13,214
31,906
The Company leases equipment under capital leases with a weighted-average interest rate of 4.48%. As of
December 31, 2018, future payments under these capital leases were as follows (in thousands):
Fiscal year:
2019
2020
2021
2022
2023
Thereafter
Total minimum lease payments
Less amount representing interest
Capital lease obligations
Less current portion
Capital lease obligations, less current portion
$
$
883
742
656
540
529
1,868
5,218
(749)
4,469
(693)
3,776
The value of the equipment under capital leases as of December 31, 2018 was $6.1 million, with related accumulated
amortization of $1.8 million.
The Company also leases certain fueling station equipment to a certain customer under a sales-type lease at an interest
rate of 13.5%.
102
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
As of December 31, 2018, future receipts under this lease were as follows (in thousands):
Fiscal year:
2019
2020
2021
2022
2023
Thereafter
Capital lease receivables
Less amount representing interest
Capital lease receivables, less current portion
Note 18 —401(k) Plan
$
$
186
186
186
186
186
1,240
2,170
(1,080)
1,090
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 also make discretionary
contributions to the Savings Plans, subject to limitations. For each of the years ended December 31, 2017, 2018, and 2019
the Company contributed approximately $1.3 million of matching contributions to the Savings Plan.
Note 19 – Net Income (Loss) Per Share
The following table sets forth the computations of basic and diluted earnings per share for the years ended
December 31, 2017, 2018 and 2019 (in thousands, except share and per share amounts):
Net income (loss)
$
2017
(79,237) $
2018
2019
(3,790) $
20,421
Weighted average common shares outstanding
Dilutive effect of potential common shares from restricted stock units
and stock options
Weighted average common shares outstanding - diluted
Basic income (loss) per share
Diluted income (loss) per share
$
$
150,430,239
180,655,435
204,573,287
—
150,430,239
—
180,655,435
(0.53) $
(0.53) $
(0.02) $
(0.02) $
1,414,222
205,987,509
0.10
0.10
The following potentially dilutive securities have been excluded from the diluted net income (loss) per share
calculations because their effect would have been antidilutive. Although these securities were antidilutive for these periods,
they could be dilutive in future periods.
2017
2018
8,613,854 8,699,677 7,652,463
14,991,521 3,164,557 3,164,557
—
1,832,575 2,279,601
2019
(in shares)
Stock options
Convertibles notes
Restricted stock units
103
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Note 20 —Related Party Transactions
During the year ended December 31, 2019, the Company sold RINs to a related party for proceeds of $1.7 million in
the ordinary course of business.
During the year ended December 31, 2019, the Company paid a related party $0.9 million for expenses incurred in
the ordinary course of business and swap settlements on commodity swap contracts (Note 8 and Note 9). The amount due
to the related party as of December 31, 2019 is immaterial.
Note 21 —Reportable Segments and Geographic Information
Disclosures are required for certain information regarding operating segments, products and services, geographic areas
of operation and major customers. Segment reporting is based upon the “management approach,” which assesses, how
management organizes the Company’s operating segments for which separate financial information is (1) available and
(2) evaluated regularly by the Chief Operating Decision Maker (“CODM”) in deciding how to allocate resources and in
assessing performance. The Company’s CODM is its Chief Executive Officer.
The Company operates in a single segment to sell natural gas. In making operating decisions, the CODM primarily
considers consolidated financial information, accompanied by volumes delivered information. The assessment of operating
results and the allocation of resources among the components of the business are made by the CODM and are based on
gross margins and volumes delivered by market sector and volume type. Contracts are evaluated based on the economics
of a mix of products and services for a customer.
The table below presents the Company’s revenue, operating income (loss) and long-lived assets by geographic area
(in thousands). 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.
Geographic revenue data reflect internal allocations and are therefore subject to certain assumptions and the Company’s
methodology. Accordingly, revenue, operating income (loss), and long-lived assets shown for each geographic area may
not be the amounts that would have been reported if the geographic areas were independent of one another. Revenue by
geographic area is categorized based on where services are rendered and finished goods are sold. Operating income (loss)
by geographic area is categorized based on the location of the entity selling the finished goods or providing the services.
Long-lived assets by geographic are categorized based on the location of the assets.
2017
2018
2019
Revenue:
United States
Canada
Other
Total revenue
Operating income (loss):
United States
Canada
Other
Total operating income (loss)
Long-lived assets:
United States
Canada
Other
Total long-lived assets
104
$ 316,756 $ 337,531 $ 338,549
5,516
—
$ 341,599 $ 346,419 $ 344,065
6,846
17,997
8,888
—
$ (96,228) $
(9,495)
(28,724)
$ (134,447) $
3,548 $
347
—
3,895 $
10,805
(877)
—
9,928
$ 465,245 $ 442,897 $ 415,548
226
—
$ 465,618 $ 443,182 $ 415,774
285
—
373
—
CLEAN ENERGY FUELS CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The Company’s goodwill and intangible assets as of December 31, 2017, 2018, and 2019 relate to its United States
operations, and its subsidiaries, Clean Energy Cryogenics and NG Advantage (see Note 5).
Note 22 —Concentrations
During the years ended December 31, 2017, 2018, and 2019, two, two, and three suppliers, respectively, each
accounted for 10% or more of the Company’s natural gas expense related to CNG and LNG purchases.
During the years ended December 31, 2017, 2018, and 2019, no single customer accounted for 10% or more of the
Company’s total revenue.
Note 23 —Subsequent Events
In February 2020, the Company converted the principal and accrued interest under the November 2019 Convertible
Note into common units of NG Advantage resulting in an increase in the Company’s controlling interest in NG Advantage
to 93.2%.
105
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
We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed
in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the
time periods specified in the rules and forms of the SEC, and that such information is accumulated and communicated to
our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely
decisions regarding required disclosure.
Our management carried out an evaluation, with the participation of our Chief Executive Officer and Chief Financial
Officer (our principal executive and principal financial officers, respectively) of the effectiveness of our disclosure controls
and procedures as of December 31, 2019, the end of the period covered by this report. Based on this evaluation, our Chief
Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of
December 31, 2019.
Changes in Internal Control Over Financial Reporting
We regularly review and evaluate our internal control over financial reporting, and from time to time we may make
changes to our processes and systems to improve controls or increase efficiencies. Such changes may include, among
others, implementing new and more efficient systems, consolidating activities, and migrating processes.
There were no changes in our internal control over financial reporting that occurred during the quarter ended
December 31, 2019 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 financial reporting (as
defined in Rule 13a-15(f) under the Exchange Act) for our Company. Our management, with the participation of our Chief
Executive Officer and Chief Financial Officer, assessed the effectiveness of our internal control over financial reporting
as of December 31, 2019. In making this assessment, our management used the criteria set forth by the Committee of
Sponsoring Organizations of the Treadway Commission in Internal Control—Integrated Framework (2013). Based on
this assessment, our management concluded that, as of December 31, 2019, our internal control over financial reporting
was effective. Our independent registered public accounting firm, KPMG LLP, has issued an attestation report on our
internal control over financial reporting, which is included in Item 8. Financial Statements and Supplementary Data of this
report.
Inherent Limitations of Disclosure Controls and Procedures and Internal Control Over Financial Reporting
In designing our disclosure controls and procedures and internal control over financial reporting, management
recognizes that any controls and procedures, no matter how well-designed and operated, can provide only reasonable
assurance of achieving the desired control objectives. In addition, the design of our controls and procedures must reflect
the fact that there are resource constraints, and management necessarily applies its judgment in evaluating the benefits of
possible controls and procedures relative to their costs. Because of these inherent limitations, our disclosure and internal
controls may not prevent or detect all instances of fraud, misstatements or other control issues. In addition, projections of
any evaluation of the effectiveness of disclosure or internal controls to future periods are subject to risks, including, among
others, that controls may become inadequate because of changes in conditions or that compliance with policies or
procedures may deteriorate.
106
Item 9B. Other Information.
None.
107
Item 10. Directors, Executive Officers and Corporate Governance.
PART III
We have adopted a written code of ethics that applies to our employees, officers and directors, including our principal
executive officer, principal financial officer, principal accounting officer or controller, or persons performing similar
functions. A current copy of the code is posted under “Corporate Governance” on the Investor Relations section of our
website, www.cleanenergyfuels.com. To the extent required by applicable rules adopted by the SEC and the Nasdaq Stock
Market LLC, we intend to disclose future amendments to certain provisions of the code, or waivers of such provisions
granted to executive officers and directors, in this location on our website at www.cleanenergyfuels.com.
The remaining information required by this item is incorporated by reference to the disclosure under (i) “Proposal 1:
Election of Directors-General,” “Proposal 1: Election of Directors-Director Nominees” and “Information About Executive
Officers,” as it relates to the information about our directors, director nominees and executive officers required by Item 401
of Regulation S-K promulgated by the SEC, (ii) “Other Matters-Delinquent Section 16(a) Reports,” and (iii) “Corporate
Governance-Board and Committee Composition” and “Corporate Governance-Board Committees,” as it relates to the
information about the audit committee of our Board of Directors required by Item 407(d)(4) and (d)(5) of Regulation S-K
promulgated by the SEC, in each case in our definitive proxy statement for our 2020 annual meeting of stockholders to be
filed with the SEC within 120 days after the end of our fiscal year ended December 31, 2019.
Item 11. Executive Compensation.
The information required by this item is incorporated by reference to the disclosure under “Compensation Discussion
and Analysis,” “Executive Compensation,” “Director Compensation” and “Compensation Committee Report,” in each
case in our definitive proxy statement for our 2020 annual meeting of stockholders to be filed with the SEC within 120 days
after the end of our fiscal year ended December 31, 2019.
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 disclosure under “Security Ownership of
Certain Beneficial Owners and Management” and “Equity Compensation Plans-Securities Authorized for Issuance Under
Equity Compensation Plans,” in each case in our definitive proxy statement for our 2020 annual meeting of stockholders
to be filed with the SEC within 120 days after the end of our fiscal year ended December 31, 2019.
Item 13. Certain Relationships and Related Transactions and Director Independence.
The information required by this item is incorporated by reference to the disclosure under (i) “Corporate Governance-
Board and Committee Composition”, as it relates to the information about director independence required by
Item 407(a) of Regulation S-K promulgated by the SEC, and (ii) “Certain Relationships and Related Party Transactions,”
in each case in our definitive proxy statement for our 2020 annual meeting of stockholders to be filed with the SEC within
120 days after the end of our fiscal year ended December 31, 2019.
Item 14. Principal Accountant Fees and Services.
The information required by this item is incorporated by reference to the disclosure under “Proposal 2: Ratification
of Appointment of Independent Registered Public Accounting Firm-Independent Registered Public Accounting Firm Fees
and Services” and “Proposal 2: Ratification of Appointment of Independent Registered Public Accounting Firm-Pre-
Approval Policies and Procedures,” in each case in our definitive proxy statement for our 2020 annual meeting of
stockholders to be filed with the SEC within 120 days after the end of our fiscal year ended December 31, 2019.
108
Item 15. Exhibits and Financial Statement Schedules.
(a)(1) Consolidated Financial Statements
PART IV
The following items are filed in Item 8. Financial Statements and Supplementary Data of this report:
Report of Independent Registered Public Accounting Firm
Consolidated Balance Sheets
Consolidated Statements of Operations
Consolidated Statements of Comprehensive Income (Loss)
Consolidated Statements of Stockholders’ Equity
Consolidated Statements of Cash Flows
Notes to Consolidated Financial Statements
(a)(2) Financial Statement Schedules
The financial statement schedule set forth below is filed as a part of this report. All other schedules have been omitted
because they are not required, not applicable, or the required information is otherwise included.
Schedule II - Valuation and Qualifying Accounts
(In thousands)
Allowances for Allowance for
Doubtful Trade Doubtful Notes
Balance as of December 31, 2016
Charges (benefit) to operations
Deductions
Balance as of December 31, 2017
Charges (benefit) to operations
Deductions
Balance as of December 31, 2018
Charges (benefit) to operations
Deductions
Balance as of December 31, 2019
(a)(3) Exhibits
$
$
Receivables
1,063 $
395
(182)
1,276
1,169
(526)
1,919
908
(415)
2,412 $
Receivables
1,230
3,344
(30)
4,544
—
(381)
4,163
931
(1,763)
3,331
The information required by this Item 15(a)(3) is set forth on the exhibit index, which immediately precedes the
signature page to this report and is incorporated herein by reference.
Item 16. Form 10-K Summary.
We have elected not to provide summary information.
109
Exhibit
Number
Description
2.11§
Asset Purchase Agreement dated
Incorporated herein by reference to the following filings:
Form
Filed as Exhibit 2.11 to the Current Report
Filed on
March 1, 2017
EXHIBIT INDEX
February 27, 2017, by and among Clean
Energy Renewable Fuels, LLC, BP
Products North America, Inc. and, solely
with respect to Article VIII thereof, Clean
Energy and BP Corporation North
America, Inc.
on Form 8-K.
2.12§
Investment Agreement dated
November 26, 2017, by and between Clean
Energy and Landi Renzo S.p.A.
Filed as Exhibit 2.12 to the Current Report
on Form 8-K.
November 27,
2017
3.1
Restated Certificate of Incorporation, as
Filed as Exhibit 3.1 to the Quarterly Report
August 7, 2018
amended by the Certificate of Amendment
to the Restated Certificate of Incorporation
of the Registrant dated May 28, 2010, as
further amended by the Certificate of
Amendment to the Restated Certificate of
Incorporation of the Registrant dated
May 8, 2014.
on Form 10-Q for the quarter ended
June 30, 2018.
3.1.1
Certificate of Amendment to the Restated
Filed as Exhibit 3.1.1 to the Quarterly
August 7, 2018
Certificate of Incorporation of Clean
Energy Fuels Corp. dated June 8, 2018.
Report on Form 10-Q for the quarter ended
June 30, 2018.
3.2
Amended and Restated Bylaws.
Filed as Exhibit 3.2 to the Current Report
February 23,
on Form 8-K.
2011
3.2.1
Amendment No. 1 to Amended and
Filed as Exhibit 3.2.1 to the Current Report
February 27,
Restated Bylaws.
on Form 8-K.
2014
4.1
Specimen Common Stock Certificate.
Filed as Exhibit 4.1 to the Registration
Statement on Form S-1, as amended.
March 27, 2007
4.10
Form of Replacement Note issued by the
Filed as Exhibit 4.9 to the Current Report
June 18, 2013
Registrant.
on Form 8-K.
4.11*
Description of Clean Energy Fuels Corp.
Capital Stock.
10.4+
Form of Indemnification Agreement.
Filed as Exhibit 10.4 to the Registration
Statement on Form S-1, as amended.
March 27, 2007
10.7+
2006 Equity Incentive Plan—Form of
Filed as Exhibit 99.5 to the Registration
August 14, 2007
Notice of Stock Option Grant and Stock
Option Agreement.
Statement on Form S-8.
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
110
Exhibit
Number
Description
10.16+
2006 Equity Incentive Plan—Form of
Stock Award Agreement.
Incorporated herein by reference to the following filings:
Form
Filed as Exhibit 10.2 to the Quarterly
Filed on
May 15, 2008
Report on Form 10-Q for the quarter ended
March 31, 2008.
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
10.80
Lease dated March 18, 2013, between The
Irvine Company LLC and Clean Energy.
Filed as Exhibit 10.80 to the Quarterly
May 8, 2013
Report on Form 10-Q for the quarter ended
March 31, 2013.
10.81
10.83
First Amendment to Lease dated April 17,
2013, between The Irvine Company LLC
and Clean Energy.
Filed as Exhibit 10.81 to the Quarterly
May 8, 2013
Report on Form 10-Q for the quarter ended
March 31, 2013.
Note Purchase Agreement dated June 14,
2013, among the Registrant, Chesapeake
NG Ventures Corporation, Boone Pickens
and Green Energy Investment Holdings,
LLC.
Filed as Exhibit 10.83 to the Current
June 18, 2013
Report on Form 8-K.
10.84
Loan Agreement dated June 14, 2013,
Filed as Exhibit 10.84 to the Current
June 18, 2013
between the Registrant and Green Energy
Investment Holdings, LLC.
Report on Form 8-K.
10.85
Loan Agreement dated June 14, 2013,
Filed as Exhibit 10.85 to the Current
June 18, 2013
between the Registrant and Boone Pickens.
Report on Form 8-K.
10.86
10.87
Registration Rights Agreement dated
June 14, 2013, among the Registrant,
Boone Pickens and Green Energy
Investment Holdings, LLC.
Filed as Exhibit 10.86 to the Current
June 18, 2013
Report on Form 8-K.
Marketing Agreement dated June 28, 2013,
among Clean Energy, Westport Power Inc.
and Westport Fuel Systems Inc.
Filed as Exhibit 10.87 to the Current
June 28, 2013
Report on Form 8-K.
10.90+
Clean Energy Fuels Corp. Employee Stock
Filed as Exhibit Annex A to Schedule 14A
March 28, 2013
Purchase Plan.
Definitive Proxy Statement.
10.92†
Liquefied Natural Gas Fueling Station and
Filed as Exhibit 10.92 to the Annual
February 27,
LNG Master Sales Agreement dated
August 2, 2010, between Clean Energy and
Pilot Travel Centers, LLC.
Report on Form 10-K for the year ended
December 31, 2013.
2014
10.94
Form of Common Unit Purchase
Filed as Exhibit 10.94 to the Current
October 15,
Agreement dated October 14, 2014, among
Report on Form 8-K.
2014
111
Exhibit
Number
Description
Form
Filed on
Incorporated herein by reference to the following filings:
NG Advantage, LLC, Clean Energy and
the other investors named therein.
10.103+ Amended and Restated 2006 Equity
Filed as Exhibit 10.103 to the Quarterly
May 11, 2015
Incentive Plan - Form of Notice of Stock
Unit Award.
Report on Form 10‑Q for the quarter ended
March 31, 2015.
10.104+ 2006 Equity Incentive Plan - Form of
Filed as Exhibit 10.104 to the Quarterly
May 11, 2015
Notice of Stock Option Grant.
Report on Form 10‑Q for the quarter ended
March 31, 2015.
10.106+ Amended and Restated Employment
Filed as Exhibit 10.106 to the Current
December 31,
Agreement dated December 31, 2015,
between the Registrant and Andrew J.
Littlefair.
Report on Form 8‑K.
2015
10.107+ Amended and Restated Employment
Filed as Exhibit 10.107 to the Current
December 31,
Agreement dated December 31, 2015,
between the Registrant and Robert M.
Vreeland.
Report on Form 8‑K.
2015
10.108+ Amended and Restated Employment
Filed as Exhibit 10.108 to the Current
December 31,
Agreement dated December 31, 2015,
between the Registrant and Mitchell W.
Pratt.
Report on Form 8‑K.
2015
10.109+ Amended and Restated Employment
Filed as Exhibit 10.109 to the Current
December 31,
Agreement dated December 31, 2015,
between the Registrant and Barclay F.
Corbus.
Report on Form 8‑K.
2015
10.111
Promissory Note dated February 29, 2016,
between the Registrant, Clean Energy and
PlainsCapital Bank.
Filed as Exhibit 10.111 to the Annual
March 3, 2016
Report on Form 10-K for the year ended
December 31, 2015.
10.112
Pledged Account Agreement dated
Filed as Exhibit 10.112 to the Annual
March 3, 2016
February 29, 2016, between Clean Energy,
PlainsCapital Bank and PlainsCapital
Bank - Wealth Management and Trust.
Report on Form 10-K for the year ended
December 31, 2015.
10.113
Loan and Security Agreement dated
Filed as Exhibit 10.113 to the Annual
March 3, 2016
February 29, 2016, between the Registrant,
Clean Energy and PlainsCapital Bank.
Report on Form 10-K for the year ended
December 31, 2015.
10.114+ Clean Energy Fuels Corp. 2016
Filed as Exhibit 10.114 to the Current
May 27, 2016
Performance Incentive Plan.
Report on Form 8-K.
10.116
Loan Modification Agreement dated
Filed as Exhibit 10.116 to the Quarterly
November 3,
October 31, 2016, between the Registrant,
Clean Energy and PlainsCapital Bank.
Report on Form 10-Q for the quarter ended
September 30, 2016.
2016
112
Exhibit
Number
Description
10.117+ Clean Energy Fuels Corp. 2016
Incorporated herein by reference to the following filings:
Form
Filed as Exhibit 10.117 to the Quarterly
Filed on
August 9, 2016
Performance Incentive Plan-Form of
Notice of Stock Option Grant and Terms
and Conditions of Nonqualified Stock
Option.
Report on Form 10-Q for the quarter ended
June 30, 2016.
10.118+ Clean Energy Fuels Corp. 2016
Filed as Exhibit 10.118 to the Quarterly
August 9, 2016
Performance Incentive Plan-Form of
Notice of Stock Unit Award and Terms and
Conditions of Stock Unit Award.
Report on Form 10-Q for the quarter ended
June 30, 2016.
10.120+ Form of Option Surrender Agreement.
Filed as Exhibit 10.120 to the Quarterly
May 4, 2017
Report on Form 10-Q for the quarter ended
March 31, 2017.
10.122
Series A Preferred Units Issuance
Filed as Exhibit 10.122 to the Quarterly
November 2,
Agreement dated July 14, 2017, by and
between Clean Energy and NG Advantage
LLC.
Report on Form 10-Q for the quarter ended
September 30, 2017.
2017
10.125
Stock Purchase Agreement dated May 9,
2018, between the Registrant and Total
Market Services, S.A.
Filed as Exhibit 10.125 to the Quarterly
May 10, 2018
Report on Form 10-Q for the quarter ended
March 31, 2018.
10.126
Voting Agreement dated May 9, 2018,
among the Registrant, Total Market
Services, S.A., and the directors and
officers of the Registrant signatory.
Filed as Exhibit 10.126 to the Quarterly
May 10, 2018
Report on Form 10-Q for the quarter ended
March 31, 2018.
10.127
Form of Registration Rights Agreement
Filed as Exhibit 10.127 to the Quarterly
May 10, 2018
dated June 13, 2018, between the
Registrant and Total Market Services, S.A.
Report on Form 10-Q for the quarter ended
March 31, 2018.
10.128
Common Unit Purchase Agreement, dated
Filed as Exhibit 1.128 to the Annual
March 12, 2019
October 1, 2018, by and among NG
Advantage, LLC, Clean Energy and the
other investors named therein.
Report on Form 10-K for the year ended
December 31, 2018.
10.129
Term Credit Agreement, dated as of
Filed as Exhibit 1.129 to the Annual
March 12, 2019
January 2, 2019, between the Registrant
and Société Générale.
Report on Form 10-K for the year ended
December 31, 2018.
10.130
Credit Support Agreement, dated as of
January 2, 2019, by and between the
Registrant and Total Holdings USA, Inc.
Filed as Exhibit 1.130 to the Annual
March 12, 2019
Report on Form 10-K for the year ended
December 31, 2018.
10.131
Note Purchase Agreement, dated
February 15, 2019, between NG
Advantage, LLC and Clean Energy.
Filed as Exhibit 10.131 to the Quarterly
May 9, 2019
Report on Form 10-Q for the quarter ended
March 31, 2019.
10.132
Convertible Promissory Note, dated
February 15, 2019, between NG
Advantage, LLC and Clean Energy.
Filed as Exhibit 10.132 to the Quarterly
May 9, 2019
Report on Form 10-Q for the quarter ended
March 31, 2019.
113
Exhibit
Number
Description
Form
Filed on
Incorporated herein by reference to the following filings:
10.133
Form of Note Purchase Agreement,
Filed as Exhibit 10.133 to the Quarterly
August 8, 2019
Convertible Promissory Note and Warrant
to Purchase Common Units, dated June 28,
2019, between NG Advantage, LLC and
Clean Energy.
Report on Form 10-Q for the quarter ended
June 30, 2019.
10.134* Form of Note Purchase Agreement,
Convertible Promissory Note and Warrant
to Purchase Common Units, dated
November 27, 2019, between NG
Advantage, LLC and Clean Energy.
21.1*
Subsidiaries.
23.1*
Consent of Independent Registered Public
Accounting Firm KPMG LLP.
24.1*
Power of Attorney (included on the
signature page to this report).
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 Exchange Act of 1934, as
adopted pursuant to Section 302 of the
Sarbanes- Oxley Act of 2002.
31.2*
Certification of Robert M. Vreeland, Chief
Financial Officer, pursuant to Rule
13a-14(a) or 15d-14(a) of the Securities
Exchange Act of 1934, as adopted pursuant
to Section 302 of the Sarbanes-Oxley Act
of 2002.
32.1**
Certification pursuant to 18 U.S.C. Section
1350, as adopted pursuant to Section 906
of the Sarbanes-Oxley Act of 2002,
executed by Andrew J. Littlefair, President
and Chief Executive Officer, and Robert
M. Vreeland Chief Financial Officer.
99.1
Natural Gas Hedge Policy dated May 29,
Filed as Exhibit 99.1 to the Current Report
June 20, 2008
2008.
on Form 8-K.
101
The following materials from the
Registrant’s Annual Report on Form 10-K
for the year ended December 31, 2019,
formatted in XBRL (eXtensible Business
Reporting Language):
(i) Consolidated Balance Sheets;
(ii) Consolidated Statements of Operations;
114
Exhibit
Number
Description
Form
Filed on
Incorporated herein by reference to the following filings:
(iii) Consolidated Statements of
Comprehensive Income (Loss);
(iv) Consolidated Statements of
Stockholders’ Equity;
(v) Consolidated Statements of Cash
Flows; and
(vi) Notes to Consolidated Financial
Statements.
§ Schedules and exhibits omitted pursuant to Item 601(b)(2) of Regulation S-K promulgated by the SEC.
† Portions of this exhibit have been omitted pursuant to the grant of a request for confidential treatment and the non-
public information has been filed separately with the SEC.
* Filed herewith.
** Furnished herewith.
+ Management contract or compensatory plan or arrangement.
115
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.
SIGNATURES
CLEAN ENERGY FUELS CORP.
By:
/s/ ANDREW J. LITTLEFAIR
Andrew J. Littlefair
President and Chief Executive Officer
Date: March 10, 2020
POWER OF ATTORNEY
IN WITNESS WHEREOF, each person whose signature appears below constitutes and appoints Andrew J. Littlefair
and Robert M. Vreeland as his true and lawful agent, proxy and attorney-in-fact, each acting alone, with full power of
substitution and resubstitution, for him and in his name, place and stead, in any and all capacities, to (i) act on and sign
any amendments to this report, with exhibits thereto and other documents in connection therewith, (ii) act on and sign such
certificates, instruments, agreements and other documents as may be necessary or appropriate in connection therewith, and
in each case file the same with the Securities and Exchange Commission, hereby approving, ratifying and confirming all
that such agent, proxy and attorney-in-fact or any of his substitutes may lawfully do or cause to be done by virtue thereof.
116
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
/s/ ROBERT M. VREELAND
Robert M. Vreeland
/s/ STEPHEN A. SCULLY
Stephen A. Scully
President, Chief Executive Officer (Principal
Executive Officer) and Director
March 10, 2020
Chief Financial Officer (Principal Financial Officer
and Principal Accounting Officer)
March 10, 2020
Chairman of the Board and Director
March 10, 2020
/s/ LIZABETH ARDISANA
Lizabeth Ardisana
Director
/s/ PHILIPPE CHARLEUX
Philippe Charleux
Director
/s/ JOHN S. HERRINGTON
John S. Herrington
Director
/s/ JAMES C. MILLER III
James C. Miller III
Director
/s/ PHILIPPE MONTANTÊME
Philippe Montantême
Director
/s/ JAMES E. O’CONNOR
James E. O’Connor
Director
/s/ KENNETH M. SOCHA
Kenneth M. Socha
Director
/s/ VINCENT C. TAORMINA
Vincent C. Taormina
Director
March 10, 2020
March 10, 2020
March 10, 2020
March 10, 2020
March 10, 2020
March 10, 2020
March 10, 2020
March 10, 2020
117