2019
A N N U A L R E P O R T
Printed on recycled paper.
© 2020 Ameresco, Inc. Ameresco and the Ameresco logo, the orb symbol and the tagline
“Green. Clean. Sustainable.” are registered in the U.S. Patent and Trademark Office. All rights reserved.
DIRECTORS
EXECUTIVE OFFICERS
George P. Sakellaris
Chairman, President and Chief Executive Officer, Ameresco
George P. Sakellaris
Chairman, President and Chief Executive Officer
David J. Anderson
Executive Vice President, Ameresco
David J. Anderson
Executive Vice President
David J. Corrsin
Executive Vice President, General Counsel and Secretary, Ameresco
Michael T. Bakas
Executive Vice President, Distributed Energy Systems
Douglas I. Foy
President, Serrafix Corporation
Nicole A. Bulgarino
Executive Vice President and General Manager, Federal Solutions
Spencer Doran Hole
Senior Vice President and Chief Financial Officer, Ameresco
Mark A. Chiplock
Vice President and Chief Accounting Officer
Jennifer L. Miller
Chief Business Sustainability Officer (Retired), Sappi North America
David J. Corrsin
Executive Vice President, General Counsel and Secretary
Thomas S. Murley
Principal, Two Lights Energy Advisors LLC
Spencer Doran Hole
Senior Vice President and Chief Financial Officer
Nickolas Stavropoulos
President and Chief Operating Officer (Retired), Pacific Gas and
Electric Company
Louis P. Maltezos
Executive Vice President
SHAREHOLDER INFORMATION
Copies of all SEC filings, including our 10-K, are available
on our website under the Investor Relations section.
GENERAL INFORMATION
Ameresco Inc.
1-866-AMERESCO
info@ameresco.com
Joseph W. Sutton
Chief Executive Officer, Sutton Ventures Group
Frank V. Wisneski
Partner (Retired), Wellington Management Company
CORPORATE HEADQUARTERS
Ameresco Inc.
111 Speen Street
Suite 410
Framingham, MA 01701
508.661.2200
ameresco.com
STOCK LISTING
Our common stock is traded on the New York Stock
Exchange under the symbol AMRC.
Transfer Agent
American Stock Transfer and Trust
New York, NY
VISION
Energizing a sustainable world.
MISSION
Leading the quest to change the world as the trusted sustainability partner
creating valued, single-sourced, efficient energy solutions delivered with
passion, expertise, teamwork and a relentless focus on customer satisfaction.
VALUES
Ameresco’s values shape our culture and the way we conduct business. Our
values are aligned with CARING about our stakeholders and are instrumental
in guiding every aspect of our business.
Bringing Long-Term Value to Customers Since 2000
Ameresco (NYSE:AMRC) is a leading energy services company with a comprehensive portfolio of energy efficiency and
renewable energy solutions. Our technical independence coupled with our advanced technology portfolio allows us to
integrate best-in-class solutions for the unique needs of each customer.
We provide energy efficiency services, distributed generation, analytics, supply management, and innovative facility
renewal all with practical financial solutions. Our team of technical experts deliver measurable cost savings through
customized efficiency measures. Whether focused on securing infrastructure upgrades, meeting sustainability goals, or
creating resiliency, our customers benefit from a single provider of comprehensive energy solutions.
Drawing from decades of experience, Ameresco develops tailored energy projects for federal and local governments,
education, healthcare, commercial, industrial, and public housing sectors across North America and the United Kingdom.
2019 Revenue of $867M
$2.3B Project Backlog in 2019
$1.1B O&M Backlog in 2019
Energy Assets in Operation: 260 MWe
Energy Assets in Development & Construction: 321 MWe
Note: All numbers as of December 31, 2019.
Your Trusted Sustainability Partner
Ameresco is leading the quest to change the world as the trusted sustainability partner creating valued, single-sourced,
efficient energy solutions delivered with passion, expertise, teamwork, and a relentless focus on customer satisfaction.
In pursuit of energizing a sustainable world, Ameresco is proud that, in 2019, our renewable energy assets and
customer projects delivered a carbon offset equivalent to 11,167,978 metric tons of CO2.
Aggregate Metric Tons of CO2 Avoided Per Year
2019 Carbon Offset is Equal to One of...
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Greenhouse gas emissions from
27,712,104,218 miles driven
by an average passenger vehicle.
Carbon dioxide emissions from
1,288,712 homes’ energy
use for one year.
Carbon sequestered by
14,584,861 acres of U.S.
forests in one year.
2011
2012
2013
2014
2015
2016
2017
2018
2019
Note: Data estimates based on assets owned and operating, and customer projects as of 12/31/2018 to represent carbon impact through 2019.
Letter from the CEO
Dear Shareholders,
Ameresco ended 2019 with record results across several
key metrics, and I would like to thank our employees for
their focus, dedication, and execution in delivering these
results. Our clients throughout the country continue to reach
out and demand clean and resilient energy sources. Our
investments in cutting edge advanced energy technologies
military has proved to be an important early adopter of
resiliency solutions, we are increasingly experiencing
utilities, municipalities, hospitals, higher education, and
corporations seek solutions that will enable them to rapidly
rebound from ever-increasing, widespread interruptions.
Our mission is to lead the quest in
and engineering talent positioned us to deliver the best
creating a more sustainable world.
and most flexible solutions for our customers. These
differentiators resulted in considerable positive momentum
in both contracted backlog, awarded backlog, and assets
in development as we head into 2020.
During the year, our team did an outstanding job in
leveraging the strength of every business unit to deliver
on all facets: we grew our total backlog to $2.3 billion and
our assets in development by 80% to record levels, we
converted a great number of major awards to contracts
as expected, and we executed on our contracted backlog
which enabled us to realize record revenue. We now look
forward to taking advantage of the game-changing industry
advancements.
The economics of advanced technologies have dramatically
improved and are now a key driver for renewable energy,
energy efficiency, CHP, microgrids, and energy storage
projects. Over the last decade, the cost of these advanced
technologies has dropped significantly, making many
installations and upgrades economical for our customers.
As we look to the future, it is clear that the trend is moving
towards a low or carbon free environment and away from
fossil fuels. Ameresco is well positioned to take advantage
of this trend, as we work closely with customers, providing
them with best-in-class advanced technology solutions
that fit their unique needs. We are also seeing the growing
demand for resiliency. The high-profile grid shutdowns in
California demonstrate the negative economic impact of
grid instability and power supply interruptions. While the
Moving
forward we will be reporting more ESG
(environmental, social, and governance) related data
to both our customers and investors. We are proud to
report that in 2019 alone, Ameresco’s renewable energy
assets and customer projects delivered a carbon offset
equivalent to over 11 million metric tons of CO2. This is
equivalent to the carbon absorbed by almost 15 million
acres of forests in one year.
We are entering 2020 with outstanding long-term visibility,
a great competitive advantage, and the internal resources
in place to benefit from this fast-growing market. I would
once again, like to thank both our employees, for their
dedication, hard work, and relentless execution, and our
customers, for giving us the opportunity to work with them,
for them, and beside them. I would also like to extend our
gratitude to our stockholders for their ongoing support.
As we march forward, we will do everything possible to
create as much value for all of our stakeholders in 2020
and beyond.
Sincerely,
George P. Sakellaris, PE
Chairman of the Board of Directors
President and Chief Executive Officer
Project Highlights
Portsmouth Naval Shipyard, ME
Under the $58 million task order awarded by the U.S. Navy, Ameresco is
implementing an energy resiliency project at the Portsmouth Naval Shipyard
(PNSY) in Kittery, Maine. This project expands on the long-term partnership
between Ameresco’s Federal Solutions team and the U.S. Navy at PNSY. This
Energy Savings Performance Contract (ESPC), issued as a task order on the
Department of Energy’s Super ESPC contract, features on-site generation,
battery storage, and microgrid controls to address the Navy’s priority of
maximizing energy security at the Shipyard while reducing energy costs. The
ESPC structure leverages project savings to secure third-party financing,
allowing the Navy to avoid contributing up-front funding during implementation.
Phoenix 91st Avenue Wastewater Treatment Plant, AZ
The 91st Avenue Renewable Natural Gas (RNG) plant located in Phoenix,
Arizona is the largest wastewater treatment biogas-to-RNG facility of its kind
in the United States and is capable of producing nearly 700,000 Dekatherms
of “green gas” annually. Ameresco’s processing plant beneficially utilizes
an untapped energy resource by “cleaning” raw biogas generated at the
historic 91st Ave WWTP (owned by the cities of Phoenix, Glendale, Mesa,
Scottsdale, and Tempe) into a renewable energy fuel that, through the
displacement of fossil fuel, provides valuable environmental benefits (the
reduction of 44,621 metric tons carbon equivalent or the same as removing
70,452 cars from the road annually).
National Health System Wexham Park Hospital, UK
Ameresco completed a £7.5 million energy infrastructure and maintenance
contract for NHS Wexham Park Hospital, a 588-bed acute care hospital,
serving the town of Slough and the surrounding area of Berkshire, United
Kingdom. The Energy Savings Performance Contract (ESPC) included
replacement of the hospital’s existing 1960s-era steam boilers and
distribution system with a high efficiency gas fired 1.5 MWe Combined Heat
and Power (CHP) plant. The CHP plant displaces 90% of grid electricity and
provides 75% of the hospital’s total heat requirement. Supported by a 15-
year operations and maintenance (O&M) contract, Ameresco will deliver the
hospital £700,000 in annual energy savings over the contract term.
Project Highlights
Newmarket IESO Battery Storage, ON, Canada
Ameresco worked with Ontario’s Independent Electricity System Operator
(IESO) to design and build two battery energy storage systems (BESS)
on Newmarket – Tay Power Distribution Ltd’s distribution grid. Ameresco
owns, operates, and maintains both facilities, with a total capacity of 4 MW
/ 16 MWh. This project provides critical time-shifting of energy consumption
and production and demonstrates the value of ancillary services. By
integrating the solid-state lithium-ion batteries for the grid interconnected
battery energy storage system, the facility is able to absorb power during
periods of excess energy supply and provide it back to the grid when
energy demand is high.
New York City Housing Authority (NYCHA), NY
Ameresco was found best qualified under New York City Housing Authority’s
(NYCHA’s) first round RFP for its large Energy Performance Contracting
(EPC) program and is currently completing work on its second large EPC
award. Valued at over $100 million, it’s the largest single public housing EPC
ever approved by the U.S. Department of Housing and Urban Development
(HUD), Ameresco is completing LED upgrades, heating, heating control,
ventilation, domestic hot water, and related work in 13 NYCHA properties
(nearly 15,000 apartments). Ameresco, with three others, has recently been
awarded a task order contract for additional work under NYCHA’s $400
million Indefinite Delivery Indefinite Quantity (IDIQ) EPC program.
Texas A&M University System, TX
Ameresco maintained the long-standing partnership as a pre-qualified
ESCO for the Texas A&M University System. Ameresco has been
competitively selected to perform work at four of the system’s 11 universities,
where projects have included a $14.5M energy project with Prairie View
A&M University and a $14.3M energy reduction and modernization project
at West Texas A&M University. At Texas A&M University – Corpus Christi,
Ameresco completed a $6.9M ESPC project throughout the campus, as
well as three separate design-build contracts focused on the university’s
central plant. Most recently, Ameresco was selected to implement a building
automation system retrofit at Texas A&M University in College Station, TX.
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
For the fiscal year ended December 31, 2019
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the transition period from ___________ to ___________.
Commission File Number: 001-34811
Ameresco, Inc.
(Exact name of registrant as specified in its charter)
Delaware
(State or Other Jurisdiction of
Incorporation or Organization)
111 Speen Street, Suite 410
Framingham, Massachusetts
(Address of Principal Executive Offices)
04-3512838
(I.R.S. Employer
Identification No.)
01701
(Zip Code)
(508) 661-2200
(Registrant’s Telephone Number, Including Area Code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Class A Common Stock,
par value $0.0001 per share
Name of each exchange on which registered
New York Stock Exchange
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
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
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
No
No
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 during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such
files). Yes
No
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be
contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Annual
Report on Form 10-K or any amendment to this Annual Report on Form 10-K.
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting
company, or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and
“emerging growth company” in Rule 12b-2 of the Exchange Act.
Large Accelerated Filer
Accelerated Filer
Non-accelerated filer
Smaller reporting company
Emerging growth company
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or
revised financial accounting standards provided pursuent 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
The aggregate market value of the voting and non-voting common equity held by non-affiliates computed by reference to the price at which
No
the common equity was last sold on the New York Stock Exchange on June 28, 2019, the last business day of the registrant’s most recently
completed second fiscal quarter, was $322,112,989.
Indicate the number of shares outstanding of each of the registrant’s classes of common stock as of the latest practicable date.
Class
Shares outstanding as of March 2, 2020
Class A Common Stock, $0.0001 par value per share
Class B Common Stock, $0.0001 par value per share
29,380,395
18,000,000
Portions of the definitive proxy statement for our 2020 annual meeting of stockholders are incorporated by reference into Part III.
DOCUMENTS INCORPORATED BY REFERENCE
AMERESCO, INC.
TABLE OF CONTENTS
PART I
BUSINESS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
RISK FACTORS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
UNRESOLVED STAFF COMMENTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
PROPERTIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
LEGAL PROCEEDINGS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
MINE SAFETY DISCLOSURES. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
PART II
MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER
MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES. . . . . . . . . . . . . . .
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
DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE . . . . . .
EXECUTIVE COMPENSATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
MANAGEMENT AND RELATED STOCKHOLDER MATTERS . . . . . . . . . . . . . . . . .
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR
INDEPENDENCE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
ITEM 1.
ITEM 1A.
ITEM 1B.
ITEM 2.
ITEM 3.
ITEM 4.
ITEM 5.
ITEM 6.
ITEM 7.
ITEM 7A.
ITEM 8.
ITEM 9.
ITEM 9A.
ITEM 9B.
ITEM 10.
ITEM 11.
ITEM 12.
ITEM 13.
ITEM 14.
PRINCIPAL ACCOUNTANT FEES AND SERVICES . . . . . . . . . . . . . . . . . . . . . . . . . . .
ITEM 15.
EXHIBITS AND FINANCIAL STATEMENT SCHEDULES. . . . . . . . . . . . . . . . . . . . . .
SIGNATURES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
EXHIBIT INDEX. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
PART IV
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NOTE ABOUT FORWARD LOOKING STATEMENTS
This Annual Report on Form 10-K contains “forward-looking statements” within the meaning of Section 21E of the
Securities Exchange Act of 1934, as amended (“the Exchange Act”). All statements, other than statements of historical fact,
including statements regarding our strategy, future operations, future financial position, future revenues, projected costs,
prospects, plans, objectives of management, expected market growth and other characterizations of future events or
circumstances are forward-looking statements. These statements are often, but not exclusively, identified by the use of words
such as “may,” “will,” “expect,” “believe,” “anticipate,” “intend,” “could,” “estimate,” “target,” “project,” “predict” or
“continue,” and similar expressions or variations. These forward-looking statements include, among other things, statements
about:
•
•
•
•
•
•
•
•
•
•
•
our expectations as to the future growth of our business and associated expenses;
our expectations as to revenue generation;
the future availability of borrowings under our revolving credit facility;
the expected future growth of the market for energy efficiency and renewable energy solutions;
our backlog, awarded projects and recurring revenue and the timing of such matters;
our expectations as to acquisition activity;
the impact of any restructuring;
the uses of future earnings;
our intention to repurchase shares of our Class A common stock;
the expected energy and cost savings of our projects; and
the expected energy production capacity of our renewable energy plants.
These forward-looking statements are based on current expectations and assumptions that are subject to risks, uncertainties
and other factors that could cause actual results and the timing of certain events to differ materially and adversely from the
future results expressed or implied by such forward-looking statements. Risks, uncertainties and factors that could cause or
contribute to such differences include, but are not limited to, those discussed in the section titled “Risk Factors,” set forth in
Item 1A of this Annual Report on Form 10-K and elsewhere in this report. The forward-looking statements in this Annual
Report on Form 10-K represent our views as of the date of this Annual Report on Form 10-K. Subsequent events and
developments may cause our views to change. However, while we may elect to update these forward-looking statements at
some point in the future, we have no current intention of doing so and undertake no obligation to do so except to the extent
required by applicable law. You should, therefore, not rely on these forward-looking statements as representing our views as of
any date subsequent to the date of this Annual Report on Form 10-K.
Item 1. Business
Company Overview
Founded in 2000, Ameresco, Inc. is a leading independent provider of comprehensive energy services, including energy
efficiency, infrastructure upgrades, energy security and resilience, asset sustainability and renewable energy solutions for
businesses and organizations throughout North America and Europe. Ameresco’s sustainability services include capital and
operational upgrades to a facility’s energy infrastructure and the development, construction, ownership and operation of
renewable energy plants. Ameresco has successfully completed energy saving, environmentally responsible projects with
federal, state and local governments, healthcare and educational institutions, housing authorities, and commercial and industrial
customers. With its corporate headquarters in Framingham, MA, Ameresco has more than 1,100 employees across more than 70
offices providing local expertise in the United States, Canada, and the United Kingdom.
Strategic acquisitions of complementary businesses and assets have been an important part of our historical development.
Since inception, we have completed numerous acquisitions, which have enabled us to broaden our service offerings and expand
our geographical reach.
Our principal service is the development, design, engineering and installation of projects that reduce the energy and
operations and maintenance (“O&M”) costs of our customers’ facilities. These projects generally include a variety of measures
that incorporate innovative technology and techniques, customized for the facility and designed to improve the efficiency of
major building systems, such as heating, ventilation, cooling and lighting systems, while enhancing the comfort and usability of
the buildings. Such measures may include a combination of the following: water reclamation, light-emitting diode (“LED”)
lighting, smart metering, intelligent micro-grids, battery storage, combined heat and power (“CHP”) or the installation of
renewable energy, such as solar photovoltaic (“PV”). We also offer the ability to incorporate analytical tools that provide
improved building energy management capabilities and enable customers to identify opportunities for energy cost savings. We
typically commit to customers that our energy efficiency projects will satisfy agreed upon performance standards upon
installation or achieve specified increases in energy efficiency. In most cases, the forecasted lifetime energy and operating cost
savings of the energy efficiency measures we install will defray all or almost all of the cost of such measures. In many cases,
we assist customers in obtaining third-party financing, grants or rebates for the cost of constructing the facility improvements,
resulting in little or no upfront capital expenditure by the customer. After a project is complete, we may operate, maintain and
repair the customer’s energy systems under a multi-year O&M contract, which provides us with recurring revenue and visibility
into the customer’s evolving needs.
We also serve certain customers by developing and building small-scale renewable energy plants located at or close to a
customer’s site. Depending upon the customer’s preference, we will either retain ownership of the completed plant or build it
for the customer. Most of our small-scale renewable energy plants to date consist of solar PV installations and plants
constructed adjacent to landfills, that use landfill gas (“LFG”) to generate energy. We have also designed and built, as well as
own, operate and maintain, plants that utilize biogas from wastewater treatment processes. Our largest renewable energy project
that we operate for a customer uses biomass as the primary source of energy. In the case of most of the plants that we own, the
electricity, thermal energy or processed renewable gas fuel generated by the plant is sold under a long-term supply contract with
the customer, which is typically a utility, municipality, industrial facility or other purchaser of large amounts of energy. For
information on how we finance the projects that we own and operate, please see the disclosures under Note 2, “Summary of
Significant Accounting Policies”, Note 9, “Long-Term Debt” and Note 11, “Investment Funds” to our Consolidated Financial
Statements appearing in Item 8 of this Annual Report on Form 10-K.
As of December 31, 2019, we had backlog of approximately $1,107.6 million in expected future revenues under signed
customer contracts for the installation or construction of projects, which we sometimes refer to as fully-contracted backlog. We
also had been awarded projects for which we had not yet signed customer contracts, which we sometimes refer to as awarded
projects, with estimated total future revenues of an additional $1,160.4 million. As of December 31, 2018, we had backlog of
approximately $726.6 million in expected future revenues under signed customer contracts for the installation or construction of
projects. We also had been awarded projects for which we had not yet signed customer contracts, with estimated total future
revenues of an additional $1,241.4 million. As of December 31, 2017, we had backlog of approximately $572.5 million in
expected future revenues under signed customer contracts for the installation or construction of projects. We also had been
awarded projects for which we had not yet signed customer contracts with estimated total future revenues of an additional
$1,199.0 million. The contracts reflected in our fully-contracted backlog typically have a construction period of 12 to 36
months and we typically expect to recognize revenue for such contracts over the same period. Where we have been awarded a
project, but have not yet signed a customer contract for that project, we would not begin recognizing revenue unless and until a
1 customer contract has been signed and we treat the project as fully-contracted backlog. Recently, awarded projects typically
have been taking 12 to 24 months from award to having a signed contract and thus convert to fully-contracted backlog. It may
take longer, however, depending upon the size and complexity of the project. Generally, the larger and more complex the
project, the longer it takes to take it from award to signed contract. Historically, approximately 90% of our awarded projects
ultimately have resulted in a signed contract.
See “We may not recognize all revenues from our backlog or receive all payments anticipated under awarded projects and
customer contracts” and “In order to secure contracts for new projects, we typically face a long and variable selling cycle that
requires significant resource commitments and requires a long lead time before we realize revenues” in Item 1A, Risk Factors
of this Annual Report on Form 10-K.
Revenues generated from backlog, which we refer to as project revenues, were $611.1 million, $545.1 million and $506.6
million for the twelve months ended December 31, 2019, 2018 and 2017, respectively.
We also expect to realize recurring revenues both from long-term O&M contracts and from energy output sales for
renewable energy operating assets that we own. In addition, we expect to generate revenues from the sale of photovoltaic solar
energy products and systems (“integrated-PV”) and other services, such as consulting services and enterprise energy
management services. Information about revenues from these other service and product offerings may be found in Note 20,
“Business Segment Information” of our Consolidated Financial Statements included in Item 8 of this Annual Report on Form
10-K, which information is incorporated herein by reference.
Ameresco’s Lines of Business
Projects
Our principal service is energy efficiency projects, which entails the design, engineering and installation of, and assisting
with the arranging of financing for an ever-increasing array of innovative technologies and techniques to improve the energy
efficiency, and control the operation, of a building’s energy- and water- consuming systems. In certain projects, we also design
and construct for a customer a central plant or cogeneration system providing power, heat and/or cooling to a building, or a
small-scale plant that produces electricity, gas, heat or cooling from renewable sources of energy. Our projects generally range
in size and scope from a one-month project to design and retrofit a lighting system to a more complex 30-month project to
design and install a central plant or cogeneration system or other small-scale plant. Projects we have constructed or are
currently working on include designing, engineering and installing energy conservation measures across school buildings; large,
complex energy conservation and energy security projects for the federal government; and municipal-scale street lighting
projects incorporating smart-city controls.
O&M
After an energy efficiency or renewable energy project is completed, we often provide ongoing O&M services under a
multi-year contract. These services include operating, maintaining and repairing facility energy systems such as boilers,
chillers and building controls, as well as central power and other small-scale plants. For larger projects, we frequently maintain
staff on-site to perform these services.
Energy Assets
Our service offering also includes the sale of electricity, processed renewable gas fuel, heat or cooling from the portfolio of
assets that we own and operate.
We have constructed and are currently designing and constructing a wide range of renewable energy plants using LFG,
wastewater treatment biogas, solar, biomass, other bio-derived fuels, wind and hydro sources of energy. Most of our renewable
energy projects to date have involved the generation of electricity from solar PV and LFG or the sale of processed LFG. We
purchase the LFG that otherwise would be combusted or vented, process it, and either sell it or use it in our energy plants. We
have also designed and built, as well as own, operate and maintain, plants that take biogas generated in the anaerobic digesters
of wastewater treatment plants and turn it into renewable natural gas that is either used to generate energy on-site or that can be
sold through the nation’s natural gas pipeline grid. Where we own and operate energy producing assets, we typically enter into a
long-term power purchase agreement (“PPA”) for the sale of the energy.
As of December 31, 2019, we owned and operated 99 small-scale renewable energy plants and solar PV installations. Of
the owned plants, 23 are renewable LFG plants, 2 are wastewater biogas plants, and 74 are solar PV installations. The 99 small-
2 scale renewable energy plants and solar PV installations that we own have the capacity to generate electricity or deliver
renewable gas fuel producing an aggregate of more than 259 megawatt equivalents.
Other
Our service and product offerings also include integrated-PV and consulting and enterprise energy management services.
Customer Arrangements
For our energy efficiency projects, we typically enter into energy savings performance contracts (“ESPCs”), under which
we agree to develop, design, engineer and construct a project and also commit that the project will satisfy agreed upon
performance standards that vary from project to project. These performance commitments are typically based on the design,
capacity, efficiency or operation of the specific equipment and systems we install. Depending on the project, the measurement
and demonstration may be required only once, upon installation, based on an analysis of one or more sample installations, or
may be required to be repeated at agreed upon intervals generally over periods of up to 25 years. We often assist these
customers in identifying and obtaining financing, through rebate programs, grant programs, third-party lenders and other
sources.
Under our contracts, we typically do not take responsibility for a wide variety of factors outside of our control and exclude
or adjust for such factors in commitment calculations. These factors include variations in energy prices and utility rates,
weather, facility occupancy schedules, the amount of energy-using equipment in a facility and the failure of the customer to
operate or maintain the project properly. Typically, our performance commitments apply to the aggregate overall performance
of a project rather than to individual energy efficiency measures. Therefore, to the extent an individual measure underperforms,
it may be offset by other measures that overperform during the same period. In the event that an energy efficiency project does
not perform according to the agreed upon specifications, our agreements typically allow us to satisfy our obligation by adjusting
or modifying the installed equipment, installing additional measures to provide substitute energy savings or paying the
customer for lost energy savings based on the assumed conditions specified in the agreement. Many of our equipment supply,
local design and installation subcontracts contain provisions that enable us to seek recourse against our vendors or
subcontractors if there is a deficiency in our energy reduction commitment. See “We may have liability to our customers under
our ESPCs if our projects fail to deliver the energy use reductions to which we are committed under the contract” in Item 1A,
Risk Factors.
The projects that we perform for governmental agencies are governed by particular qualification and contracting regimes.
Certain states require qualification with an appropriate state agency as a precondition to performing work or appearing as a
qualified energy service provider for state, county and local agencies within the state. For example, the Commonwealth of
Massachusetts and the states of Colorado and Washington pre-qualify energy service providers and provide contract documents
that serve as the starting point for negotiations with potential governmental clients. Most of the work that we perform for the
federal government is performed under indefinite delivery, indefinite quantity (“IDIQ”) agreements between government
agencies and us or our subsidiaries. These IDIQ agreements allow us to contract with the relevant agencies to implement energy
projects, but no work may be performed unless we and the agency agree on a task order or delivery order governing the
provision of a specific project. The government agencies enter into contracts for specific projects on a competitive basis. We
and our subsidiaries and affiliates are currently party to an IDIQ agreement with the U.S. Department of Energy expiring April
2022, which may be extended through December 2023.
Sales and Marketing
Our sales and marketing approach is to offer customers customized and comprehensive energy efficiency solutions tailored
to meet their economic, operational and technical needs. The sales, design and construction process for energy efficiency and
renewable energy projects recently has been averaging from 18 to 54 months. We identify project opportunities through
referrals, requests for proposals (“RFPs”), conferences and events, website, online campaigns, telemarketing and repeat
business from existing customers. Our direct sales force develops and follows up on customer leads. As of December 31, 2019,
we had 135 employees in direct sales.
In preparation for a proposal, our team typically conducts a preliminary audit of the customer’s needs and requirements,
and identifies areas to enhance efficiencies and reduce costs. We collect and analyze the customer’s utility bill and other data
related to energy use. If the bills are complex or numerous, we often utilize Ameresco’s enterprise energy management software
tools to scan, compile and analyze the information. Our experienced engineers visit and assess the customer’s current energy
systems and infrastructure. Through our knowledge of the federal, state, local governmental and utility environment, we assess
3 the availability of energy, utility or environmental-based payments for usage reductions or renewable power generation, which
helps us optimize the economic benefits of a proposed project for a customer. Once awarded a project, we perform a more
detailed audit of the customer’s facilities, which serves as the basis for the final specifications of the project and final contract
terms.
For renewable energy plants that are not located on a customer’s site or use sources of energy not within the customer’s
control, the sales process also involves the identification of sites with attractive sources of renewable energy and obtaining
necessary rights and governmental permits to develop a plant on that site. For example, for LFG projects, we start with gaining
control of a LFG resource located close to the prospective customer. For solar and wind projects, we look for sites where
utilities are interested in purchasing renewable energy power at rates that are sufficient to make a project feasible. Where
governmental agencies control the site and resource, such as a landfill owned by a municipality, the customer may be required
to issue an RFP to use the site or resource. Once we believe we are likely to obtain the rights to the site and the resource, we
seek customers for the energy output of the potential project, with whom we can enter into a long-term PPA.
Customers
In 2019, we served customers throughout the United States, Canada, the United Kingdom (“U.K.”), and Greece.
Historically, including for the years ended December 31, 2019, 2018 and 2017, approximately 75% of our revenues have been
derived from federal, state, provincial or local government entities, including public housing authorities and public universities.
Our federal customers include various divisions of the U.S. federal government. The U.S. federal government, which is
considered a single customer for reporting purposes, constituted 33.2%, 31.3% and 32.0% of our consolidated revenues for the
years ended December 31, 2019, 2018 and 2017, respectively. For the year ended December 31, 2019, our largest 20 customers
accounted for approximately 62.7% of our total revenues. Other than the U.S. federal government, no one customer represented
more than 10% of our revenues during this period.
See “Provisions in our government contracts may harm our business, financial condition and operating results” in Item 1A,
Risk Factors for a discussion of special considerations applicable to government contracting.
Competition
While we face significant competition from a large number of companies, we believe few offer the objective technical
expertise and full range of services that we provide.
Our principal competitors for our core business include Constellation NewEnergy (and Exelon Company), Energy Systems
Group, Honeywell, Johnson Controls, NORESCO, Schneider Electric, Siemens Building Technologies, and Trane. We compete
primarily on the basis of our comprehensive, independent offering of energy efficiency and renewable energy services and the
breadth and depth of our expertise.
For renewable energy plants, we compete primarily with many large independent power producers and utilities, as well as a
large number of developers of renewable energy projects. In the LFG market, our principal competitors include national project
developers and owners of landfills who self-develop projects using LFG from their landfills. In the solar PV market, our
principal competitors are Borrego Solar, BlueWave Solar, Citizens Energy, Clean Energy Collective, Nexamp, SunPower Corp.,
Solect Energy, and Syncarpha Capital. We compete for renewable energy projects primarily on the basis of our experience,
reputation and ability to identify and complete high quality and cost-effective projects.
For O&M services, our principal competitors are EMCOR Group, Comfort Systems USA, Honeywell, Johnson Controls
and Veolia. In this area, we compete primarily on the basis of our expertise and quality of service.
See “We operate in a highly competitive industry, and our current or future competitors may be able to compete more
effectively than we do, which could have a material adverse effect on our business, revenues, growth rates and market share” in
Item 1A, Risk Factors for further discussion of competition.
Regulatory
Various regulations affect the conduct of our business. Federal and state legislation and regulations enable us to enter into
ESPCs with government agencies in the United States. The applicable regulatory requirements for ESPCs differ in each state
and between agencies of the federal government.
4 Our projects must conform to all applicable electric reliability, building and safety, and environmental regulations and
codes, which vary from place to place and time to time. Various federal, state, provincial and local permits are required to
construct an energy efficiency project or renewable energy plant.
Renewable energy projects are also subject to specific governmental safety and economic regulation. States and the federal
government typically do not regulate the transportation or sale of LFG unless it is combined with and distributed with natural
gas, but this is not uniform among states and may change from time to time. States regulate the retail sale and distribution of
natural gas to end-users, although regulatory exemptions from regulation are available in some states for limited gas delivery
activities, such as sales only to a single customer. The sale and distribution of electricity at the retail level is subject to state and
provincial regulation, and the sale and transmission of electricity at the wholesale level is subject to federal regulation. While
we do not own or operate retail-level electric distribution systems or wholesale-level transmission systems, the prices for the
products we offer can be affected by the tariffs, rules and regulations applicable to such systems, as well as the prices that the
owners of such systems are able to charge. The construction of power generation projects typically is regulated at the state and
provincial levels, and the operation of these projects also may be subject to state and provincial regulation as “utilities.” At the
federal level, the ownership and operation of, and sale of power from, generation facilities may be subject to regulation under
the Public Utility Holding Company Act of 2005 (“PUHCA”), the Federal Power Act (“FPA”), and Public Utility Regulatory
Policies Act of 1978 (“PURPA”). However, because all of the plants that we have constructed and operated to date are small
power “qualifying facilities” under PURPA, they are subject to less regulation under the FPA, PUHCA and related state utility
laws than traditional utilities.
If we pursue projects employing different technologies or with a single project electrical capacity greater than
20 megawatts, we could become subject to some of the regulatory schemes which do not apply to our current projects. In
addition, the state, provincial and federal regulations that govern qualifying facilities and other power sellers frequently change,
and the effect of these changes on our business cannot be predicted.
LFG power generation facilities require an air emissions permit, which may be difficult to obtain in certain jurisdictions.
See “Compliance with environmental laws could adversely affect our operating results” in Item 1A, Risk Factors. Renewable
energy projects may also be eligible for certain governmental or government-related incentives from time to time, including tax
credits, cash payments in lieu of tax credits, and the ability to sell associated environmental attributes, including carbon credits.
Government incentives and mandates typically vary by jurisdiction.
Some of the demand reduction services we provide for utilities and institutional clients are subject to regulatory tariffs
imposed under federal and state utility laws. In addition, the operation of, and electrical interconnection for, our renewable
energy projects are subject to federal, state or provincial interconnection and federal reliability standards also set forth in utility
tariffs. These tariffs specify rules, business practices and economic terms to which we are subject. The tariffs are drafted by the
utilities and approved by the utilities’ state, provincial or federal regulatory commissions.
Employees
As of December 31, 2019, we had a total of 1,127 employees in offices located in 39 states, the District of Columbia, four
Canadian provinces and the U.K.
Seasonality
See “Our business is affected by seasonal trends and construction cycles, and these trends and cycles could have an adverse
effect on our operating results” in Item 1A, Risk Factors and “Overview — Effects of Seasonality” in Item 7, Management’s
Discussion and Analysis of Financial Condition and Results of Operations” for a discussion of seasonality in our business.
Segments and Geographic Information
Financial information about our domestic and international operations and about our segments may be found in Note 16,
“Geographic Information” and 20, “Business Segment Information” respectively, of our Consolidated Financial Statements
included in Item 8 of this Annual Report on Form 10-K, which information is incorporated herein by reference.
Additional Information
Ameresco was incorporated in Delaware in 2000 and is headquartered in Framingham, Massachusetts.
Periodic reports, proxy statements and other information are available to the public, free of charge, on our website,
www.ameresco.com, as soon as reasonably practicable after they have been filed with the Securities and Exchange Commission
5 (“SEC”), and through the SEC’s website, www.sec.gov. We include our website address in this report only as an inactive textual
reference and do not intend it to be an active link to our website. None of the material on our website is part of this Annual
Report on Form 10-K.
Executive Officers
The following is a list of our executive officers, their ages as of March 1, 2020 and their principal positions.
Name
George P. Sakellaris . . . . . . . . . . . .
David J. Anderson . . . . . . . . . . . . . .
Michael T. Bakas. . . . . . . . . . . . . . .
Nicole A. Bulgarino . . . . . . . . . . . .
David J. Corrsin . . . . . . . . . . . . . . .
Louis P. Maltezos . . . . . . . . . . . . . .
Spencer Doran Hole . . . . . . . . . . . .
Mark A. Chiplock . . . . . . . . . . . . . .
Age
Position (s)
73 Chairman of the Board of Directors, President and Chief Executive Officer
59 Executive Vice President and Director
51 Executive Vice President, Distributed Energy Systems
47 Executive Vice President and General Manager, Federal Solutions
61 Executive Vice President, General Counsel and Secretary and Director
53 Executive Vice President
51
Senior Vice President and Chief Financial Officer
50 Vice President of Finance and Chief Accounting Officer
George P. Sakellaris: Mr. Sakellaris has served as chairman of our board of directors and our president and chief executive
officer since founding Ameresco in 2000.
David J. Anderson: Mr. Anderson has served as our executive vice president as well as a director, since 2000 and oversees
business development, government relations, strategic marketing and communications, as well as several U.S. business units
and U.K. operations.
Michael T. Bakas: Mr. Bakas has served as our executive vice president, distributed energy systems, since November 2017.
Mr. Bakas previously served as our senior vice president, renewable energy, from March 2010 to September 2017 and our vice
president, renewable energy from 2000 to February 2010.
David J. Corrsin: Mr. Corrsin has served as our executive vice president, general counsel and secretary, as well as a
director, since 2000.
Nicole A. Bulgarino: Ms. Bulgarino has served as our executive vice president and general manager of federal solutions
since May 2017. Ms. Bulgarino previously served as our senior vice president and general manager of federal solutions from
May 2015 to May 2017; vice president and general manager of federal solutions from February 2014 to May 2015; vice
president, federal group operations from December 2012 to February 2014; director, implementation from May 2010 to
December 2012; and senior engineer from June 2004 to May 2010.
Louis P. Maltezos: Mr. Maltezos has served as executive vice president since April 2009 and oversees Central and
Northwest Regions and Canada operations. Mr. Maltezos has also served as the chief executive officer of Ameresco Canada
since September 2015 and served as the president of Ameresco Canada from September 2014 to September 2015.
Spencer Doran Hole: Mr. Hole has served as our Senior Vice President and Chief Financial Officer since July 2019. Prior
to joining Ameresco, Mr. Hole served as Chief Executive Officer, North America and Group Vice President - Strategy at
ReneSola Ltd., a manufacturer and supplier of green energy products, since November 2017 and served as the Chief Financial
Officer for the US division of ReneSola since December 2016. Prior to joining ReneSola, Mr. Hole was the founder of Coast to
Coast Advisors, an independent financial consultancy practice, assisting investor, lender and developer clients with financing
and asset sales. Mr. Hole also served as the Chief Financial Officer of Pristine Sun LLC, a small-scale solar developer, from
November 2015 through April 2016, and as a Director at Deutsche Bank from April 2007 through October 2015.
Mark A. Chiplock: Mr. Chiplock has served as Vice President of Finance and Chief Accounting Officer since July 2019.
Prior to that, Mr. Chiplock served as our Interim Chief Financial Officer and Treasurer from October 2018 through July 2019
and as our Corporate Controller from June 2014 to December 2019. Prior to Ameresco, he served as Vice President, Finance of
GlassHouse Technologies, a data center infrastructure consulting firm, from June 2012 to May 2014.
6 Item 1A. Risk Factors
Our business is subject to numerous risks. We caution you that the following important factors, among others, could cause
our actual results to differ materially from those expressed in forward-looking statements made by us or on our behalf in filings
with the SEC, press releases, communications with investors and oral statements. Any or all of our forward-looking statements
in this Annual Report on Form 10-K and in any other public statements we make may turn out to be wrong. They can be
affected by inaccurate assumptions we might make or by known or unknown risks and uncertainties. Many factors mentioned in
the discussion below will be important in determining future results. Consequently, no forward-looking statement can be
guaranteed. Actual future results may differ materially from those anticipated in forward-looking statements. We undertake no
obligation to update any forward-looking statements, whether as a result of new information, future events or otherwise, except
to the extent required by applicable law. You should, however, consult any further disclosure we make in our reports filed with
the SEC.
Risks Related to Our Business
If demand for our energy efficiency and renewable energy solutions does not develop as we expect, our revenues will suffer
and our business will be harmed.
We believe, and our growth plans assume, that the market for energy efficiency and renewable energy solutions will
continue to grow, that we will increase our penetration of this market and that our revenues from selling into this market will
continue to increase over time. If our expectations as to the size of this market and our ability to sell our products and services
in this market are not correct, our revenues will suffer and our business will be harmed.
In order to secure contracts for new projects, we typically face a long and variable selling cycle that requires significant
resource commitments and requires a long lead time before we realize revenues.
The sales, design and construction process for energy efficiency and renewable energy projects recently has been taking
from 18 to 54 months on average, with sales to federal government and housing authority customers tending to require the
longest sales processes. Our existing and potential customers generally follow extended budgeting and procurement processes,
and sometimes must engage in regulatory approval processes related to our services. Our customers often use outside
consultants and advisors, which contributes to a longer sales cycle. Most of our potential customers issue an RFP, as part of
their consideration of alternatives for their proposed project. In preparation for responding to an RFP, we typically conduct a
preliminary audit of the customer’s needs and the opportunity to reduce its energy costs. For projects involving a renewable
energy plant that is not located on a customer’s site or that uses sources of energy not within the customer’s control, the sales
process also involves the identification of sites with attractive sources of renewable energy, such as a landfill or a favorable site
for solar PV, and it may involve obtaining necessary rights and governmental permits to develop a project on that site. If we are
awarded a project, we then perform a more detailed audit of the customer’s facilities, which serves as the basis for the final
specifications of the project. We then must negotiate and execute a contract with the customer. In addition, we or the customer
typically need to obtain financing for the project.
This extended sales process requires the dedication of significant time by our sales and management personnel and our use
of significant financial resources, with no certainty of success or recovery of our related expenses. A potential customer may go
through the entire sales process and not accept our proposal. All of these factors can contribute to fluctuations in our quarterly
financial performance and increase the likelihood that our operating results in a particular quarter will fall below investor
expectations. These factors could also adversely affect our business, financial condition and operating results due to increased
spending by us that is not offset by increased revenues.
We may not recognize all revenues from our backlog or receive all payments anticipated under awarded projects and
customer contracts.
As of December 31, 2019 and December 31, 2018, we had backlog of approximately $1,107.6 million and $726.6 million,
respectively, in expected future revenues under signed customer contracts for the installation or construction of projects, which
we sometimes refer to as fully-contracted backlog; and we also had been awarded projects for which we do not yet have signed
customer contracts with estimated total future revenues of an additional $1,160.4 million and $1,241.4 million, respectively .
Our customers have the right under some circumstances to terminate contracts or defer the timing of our services and their
payments to us. In addition, our government contracts are subject to the risks described below under “Provisions in government
contracts may harm our business, financial condition and operating results.” The payment estimates for projects that have been
awarded to us but for which we have not yet signed contracts have been prepared by management and are based upon a number
7 of assumptions, including that the size and scope of the awarded projects will not change prior to the signing of customer
contracts, that we or our customers will be able to obtain any necessary third-party financing for the awarded projects, and that
we and our customers will reach agreement on and execute contracts for the awarded projects. We are not always able to enter
into a contract for an awarded project on the terms proposed. As a result, we may not receive all of the revenues that we include
in the awarded projects component of our backlog or that we estimate we will receive under awarded projects. If we do not
receive all of the revenue we currently expect to receive, our future operating results will be adversely affected. In addition, a
delay in the receipt of revenues, even if such revenues are eventually received, may cause our operating results for a particular
quarter to fall below our expectations.
Our business depends in part on federal, state, provincial and local government support for energy efficiency and renewable
energy, and a decline in such support could harm our business.
We depend in part on legislation and government policies that support energy efficiency and renewable energy projects that
enhance the economic feasibility of our energy efficiency services and small-scale renewable energy projects. This support
includes legislation and regulations that authorize and regulate the manner in which certain governmental entities do business
with us; encourage or subsidize governmental procurement of our services; encourage or in some cases require other customers
to procure power from renewable or low-emission sources, to reduce their electricity use or otherwise to procure our services;
and provide us with tax and other incentives that reduce our costs or increase our revenues. Without this support, on which
projects frequently rely for economic feasibility, our ability to complete projects for existing customers and obtain project
commitments from new customers could be adversely affected.
A substantial portion of our earnings are derived from the sale of renewable energy certificates (“RECs”) and other
environmental attributes, and our failure to be able to sell such attributes could materially adversely affect our business,
financial condition and results of operation.
A substantial portion of our earnings are attributable to our sale of renewable energy certificates (“RECs”) and other
environmental attributes generated by our energy assets. These attributes are used as compliance purposes for state-specific or
U.S. federal policy.
We own and operate solar PV installations which derive a significant portion of their revenues from the sale of solar
renewable energy certificates (“SRECs”), which are produced as a result of generating electricity. The value of these SRECs is
determined by the supply and demand of SRECs in the states in which the solar PV installations are installed. Supply is driven
by the amount of installations and demand is driven by state-specific laws relating to renewable portfolio standards.
We also own and operate renewable natural gas plants that may deliver biofuels into to the nation’s natural gas pipeline
grid. Such biofuel may qualify for certain environmental attribute mechanisms, such as renewable identification numbers
(“RINs”) which are used for compliance purposes under the Renewable Fuel Standard (“RFS”) program. The RFS is a U.S.
federal policy that requires transportation fuel to contain a minimum volume of renewable fuel. The U.S. Environmental
Protection Agency (“EPA”) administers the RFS program and may periodically undertake regulatory action involving the RFS,
including annual volume standards for renewable fuel.
We sometimes seek to sell forward a portion of our SRECs and other environmental attributes under contracts to fix the
revenues from those attributes for financing purposes or hedge against future declines in prices of such environmental
attributes. If our renewable energy facilities do not generate the amount of renewable energy attributes sold under such forward
contracts or if for any reason the renewable energy we generate does not produce SRECs or other environmental attributes for a
particular state, we may be required to make up the shortfall of SRECs or other environmental attributes under such forward
contracts through purchases on the open market or make payments of liquidated damages.
RECs are created through state law requirements for utilities to purchase a portion of their energy from renewable energy
sources and changes in state laws or regulation relating to RECs may adversely affect the availability of RECs or other
environmental attributes and the future prices for RECs or other environmental attributes, which could have an adverse effect
on our business, financial condition and results of operations.
A significant decline in the fiscal health of federal, state, provincial and local governments could reduce demand for our
energy efficiency and renewable energy projects.
8 Historically, including for the years ended December 31, 2019 and 2018, more than 75% of our revenues have been
derived from sales to federal, state, provincial or local governmental entities, including public housing authorities and public
universities. We expect revenues from this market sector to continue to comprise a significant percentage of our revenues for
the foreseeable future. A significant decline in the fiscal health of these existing and potential customers may make it difficult
for them to enter into contracts for our services or to obtain financing necessary to fund such contracts, or may cause them to
seek to renegotiate or terminate existing agreements with us. In addition, if there is a partial or full shutdown of any federal,
state, provincial or local governing body this may adversely impact our financial performance.
Provisions in our government contracts may harm our business, financial condition and operating results.
A significant majority of our fully-contracted backlog and awarded projects is attributable to customers that are
governmental entities. Our contracts with the federal government and its agencies, and with state, provincial and local
governments, customarily contain provisions that give the government substantial rights and remedies, many of which are not
typically found in commercial contracts, including provisions that allow the government to:
•
•
•
•
•
terminate existing contracts, in whole or in part, for any reason or no reason;
reduce or modify contracts or subcontracts;
decline to award future contracts if actual or apparent organizational conflicts of interest are discovered, or to impose
organizational conflict mitigation measures as a condition of eligibility for an award;
suspend or debar the contractor from doing business with the government or a specific government agency; and
pursue criminal or civil remedies under the False Claims Act, False Statements Act and similar remedy provisions
unique to government contracting.
Under general principles of government contracting law, if the government terminates a contract for convenience, the
terminated company may recover only its incurred or committed costs, settlement expenses and profit on work completed prior
to the termination. If the government terminates a contract for default, the defaulting company is entitled to recover costs
incurred and associated profits on accepted items only and may be liable for excess costs incurred by the government in
procuring undelivered items from another source. In most of our contracts with the federal government, the government has
agreed to make a payment to us in the event that it terminates the agreement early. The termination payment is designed to
compensate us for the cost of construction plus financing costs and profit on the work completed.
In ESPCs for governmental entities, the methodologies for computing energy savings may be less favorable than for non-
governmental customers and may be modified during the contract period. We may be liable for price reductions if the projected
savings cannot be substantiated.
In addition to the right of the federal government to terminate its contracts with us, federal government contracts are
conditioned upon the continuing approval by Congress of the necessary spending to honor such contracts. Congress often
appropriates funds for a program on a September 30 fiscal-year basis even though contract performance may take more than
one year. Consequently, at the beginning of many major Governmental programs, contracts often may not be fully funded, and
additional monies are then committed to the contract only if, as and when appropriations are made by Congress for future fiscal
years. Similar practices are likely to also affect the availability of funding for our contracts with Canadian, as well as state,
provincial and local government entities. If one or more of our government contracts were terminated or reduced, or if
appropriations for the funding of one or more of our contracts is delayed or terminated, our business, financial condition and
operating results could be adversely affected.
Our senior credit facility, project financing term loans and construction loans contain financial and operating restrictions
that may limit our business activities and our access to credit.
Provisions in our senior credit facility, project financing term loans and construction loans impose customary restrictions
on our and certain of our subsidiaries’ business activities and uses of cash and other collateral. These agreements also contain
other customary covenants, including covenants that require us to meet specified financial ratios and financial tests.
We have a $115 million revolving senior secured credit facility that matures June 2024, subject to the quarter end ratio
covenant described below. This facility may not be sufficient to meet our needs as our business grows, and we may be unable to
extend or replace it on acceptable terms, or at all. Under the revolving credit facility we are required to maintain a maximum
ratio of total funded debt to EBITDA (as defined in the agreement) of less than 3.25 to 1.0. We are also required to maintain a
9 debt service coverage ratio (as defined in the agreement) of at least 1.5 to 1.0. EBITDA for purposes of the facility excludes the
results of certain renewable energy projects that we own and for which financing from others remains outstanding.
In addition, our project financing term loans and construction loans require us to comply with a variety of financial and
operational covenants.
Although we do not consider it likely that we will fail to comply with any material covenants for the next twelve months,
we cannot assure that we will be able to do so. Our failure to comply with these covenants may result in the declaration of an
event of default and cause us to be unable to borrow under our credit facility. In addition to preventing additional borrowings
under this facility, an event of default, if not cured or waived, may result in the acceleration of the maturity of indebtedness
outstanding under it or the applicable project financing term loan, which would require us to pay all amounts outstanding. If an
event of default occurs, we may not be able to cure it within any applicable cure period, if at all. Certain of our debt agreements
also contain subjective acceleration clauses based on a lender deeming that a “material adverse change” in our business has
occurred. If these clauses are implicated, and the lender declares that an event of default has occurred, the outstanding
indebtedness would likely be immediately due and owing. If the maturity of our indebtedness is accelerated, we may not have
sufficient funds available for repayment or we may not have the ability to borrow or obtain sufficient funds to replace the
accelerated indebtedness on terms acceptable to us or at all.
The LIBOR calculation method may change and LIBOR is expected to be phased out after 2021.
Our senior credit facility and certain of our project financing term loans permit or require interest on the outstanding
principal balance to be calculated based on LIBOR. On July 27, 2017, the U.K. Financial Conduct Authority (the "FCA")
announced that it will no longer require banks to submit rates for the calculation of LIBOR after 2021. In the meantime, actions
by the FCA, other regulators, or law enforcement agencies may result in changes to the method by which LIBOR is calculated.
At this time, it is not possible to predict the effect of any such changes or any other reforms to LIBOR that may be enacted in
the U.K. or elsewhere.
The projects we undertake for our customers generally require significant capital, which our customers or we may finance
through third parties, and such financing may not be available to our customers or to us on favorable terms, if at all.
Our projects for customers are typically financed by third parties. For small-scale renewable energy plants that we own, we
typically rely on a combination of our working capital and debt to finance construction costs. If we or our customers are unable
to raise funds on acceptable terms when needed, we may be unable to secure customer contracts, the size of contracts we do
obtain may be smaller or we could be required to delay the development and construction of projects, reduce the scope of those
projects or otherwise restrict our operations. Any inability by us or our customers to raise the funds necessary to finance our
projects could materially harm our business, financial condition and operating results.
Project development or construction activities may not be successful, and we may make significant investments without first
obtaining project financing, which could increase our costs and impair our ability to recover our investments.
The development and construction of small-scale renewable energy plants and other energy infrastructure projects involve
numerous risks. We may be required to spend significant sums for preliminary engineering, permitting, legal and other expenses
before we can determine whether a project is feasible, economically attractive or capable of being built. In addition, we will
often choose to bear the costs of such efforts prior to obtaining project financing, prior to getting final regulatory approval and
prior to our final sale to a customer, if any.
Successful completion of a particular project may be adversely affected by numerous factors, including: failures or delays
in obtaining desired or necessary land rights, including ownership, leases and/or easements; failures or delays in obtaining
necessary permits, licenses or other governmental support or approvals, or in overcoming objections from members of the
public or adjoining land owners; uncertainties relating to land costs for projects; unforeseen engineering problems; access to
available transmission for electricity generated by our small-scale renewable energy plants; construction delays and contractor
performance shortfalls; work stoppages or labor disruptions and compliance with labor regulations; cost over-runs; availability
of products and components from suppliers; adverse weather conditions; environmental, archaeological and geological
conditions; and availability of construction and permanent financing.
If we are unable to complete the development of a small-scale renewable energy plants or fail to meet one or more agreed
target construction milestone dates, we may be subject to liquidated damages and/or penalties under the Engineering
Procurement and Construction agreement or other agreements relating to the power plant or project, and we typically will not
be able to recover our investment in the project. We expect to invest a significant amount of capital to develop projects whether
10
owned by us or by third parties. If we are unable to complete the development of a project, we may write-down or write-off
some or all of these capitalized investments, which would have an adverse impact on our net income in the period in which the
loss is recognized.
Our business is affected by seasonal trends and construction cycles, and these trends and cycles could have an adverse effect
on our operating results.
We are subject to seasonal fluctuations and construction cycles, particularly in climates that experience colder weather
during the winter months, such as the northern United States and Canada, or at educational institutions, where large projects are
typically carried out during summer months when their facilities are unoccupied. In addition, government customers, many of
which have fiscal years that do not coincide with ours, typically follow annual procurement cycles and appropriate funds on a
fiscal-year basis even though contract performance may take more than one year. Further, government contracting cycles can be
affected by the timing of, and delays in, the legislative process related to government programs and incentives that help drive
demand for energy efficiency and renewable energy projects. As a result, our revenues and operating income in the third and
fourth quarter are typically higher, and our revenues and operating income in the first quarter are typically lower, than in other
quarters of the year. As a result of such fluctuations, we may occasionally experience declines in revenue or earnings as
compared to the immediately preceding quarter, and comparisons of our operating results on a period-to-period basis may not
be meaningful.
We may have exposure to additional tax liabilities and our effective tax rate may increase or fluctuate, which could increase
our income tax expense and reduce our net income.
Our provision for income taxes is subject to volatility and could be adversely affected by changes in tax laws or
regulations, particularly changes in tax incentives in support of energy efficiency. For example, certain deductions relating to
energy efficiency have expiration dates which could significantly alter the existing tax code, including the removal of these
credits prior to their scheduled expiration. The 30% investment tax credit (“ITC”) relating to the installation of solar power
expired on December 31, 2019, after which it will fall to 26 percent in 2020, 22 percent in 2021, and 10 percent in 2022 and
future years. If these or other deductions and credits expire without being extended, or otherwise are reduced or eliminated, our
effective tax rate would increase, which could increase our income tax expense and reduce our net income.
Our tax rate has historically been significantly impacted by the IRC Section 179D deduction. This deduction is related to
energy efficient improvements we provide under government contracts. Section 179D was extended through December 31,
2020 as part of the Tax Extender and Disaster Relief Act of 2019 which became law on December 20, 2019. There is no
assurance that Section 179D will continue to be extended retroactively or otherwise and were the deduction not available it
would significantly affect our tax rate.
In addition, like other companies, we may be subject to examination of our income tax returns by the U.S. Internal
Revenue Service and other tax authorities; our U.S. federal tax returns for 2015 through 2018 are subject to audit by federal,
state and foreign tax authorities. Though we regularly assess the likelihood of adverse outcomes from such examinations and
the adequacy of our provision for income taxes, there can be no assurance that such provision is sufficient and that a
determination by a tax authority will not have an adverse effect on our net income.
Changes in the laws and regulations governing the public procurement of ESPCs could have a material impact on our
business.
We derive a significant amount of our revenue from ESPCs with our government customers. While federal, state and local
government rules governing such contracts vary, such rules may, for example, permit the funding of such projects through long-
term financing arrangements; permit long-term payback periods from the savings realized through such contracts; allow units of
government to exclude debt related to such projects from the calculation of their statutory debt limitation; allow for award of
contracts on a “best value” instead of “lowest cost” basis; and allow for the use of sole source providers. To the extent these
rules become more restrictive in the future, our business could be harmed.
Failure of third parties to manufacture quality products or provide reliable services in a timely manner could cause delays
in the delivery of our services and completion of our projects, which could damage our reputation, have a negative impact
on our relationships with our customers and adversely affect our growth.
Our success depends on our ability to provide services and complete projects in a timely manner, which in part depends on
the ability of third parties to provide us with timely and reliable products and services. In providing our services and completing
11 our projects, we rely on products that meet our design specifications and components manufactured and supplied by third
parties, as well as on services performed by subcontractors.We also rely on subcontractors to perform substantially all of the
construction and installation work related to our projects; and we often need to engage subcontractors with whom we have no
experience for our projects.
If any of our subcontractors are unable to provide services that meet or exceed our customers’ expectations or satisfy our
contractual commitments, our reputation, business and operating results could be harmed. In addition, if we are unable to avail
ourselves of warranty and other contractual protections with providers of products and services, we may incur liability to our
customers or additional costs related to the affected products and components, which could have a material adverse effect on
our business, financial condition and operating results. Moreover, any delays, malfunctions, inefficiencies or interruptions in
these products or services could adversely affect the quality and performance of our solutions and require considerable expense
to establish alternate sources for such products and services. This could cause us to experience difficulty retaining current
customers and attracting new customers, and could harm our brand, reputation and growth.
We may have liability to our customers under our ESPCs if our projects fail to deliver the energy use reductions to which we
are committed under the contract.
For our energy efficiency projects, we typically enter into ESPCs under which we commit that the projects will satisfy
agreed-upon performance standards appropriate to the project. These commitments are typically structured as guarantees of
increased energy efficiency that are based on the design, capacity, efficiency or operation of the specific equipment and systems
we install. Our commitments generally fall into three categories: pre-agreed, equipment-level and whole building-level. Under
a pre-agreed efficiency commitment, our customer reviews the project design in advance and agrees that, upon or shortly after
completion of installation of the specified equipment comprising the project, the pre-agreed increase in energy efficiency will
have been met. Under an equipment-level commitment, we commit to a level of increased energy efficiency based on the
difference in use measured first with the existing equipment and then with the replacement equipment upon completion of
installation. A whole building-level commitment requires future measurement and verification of increased energy efficiency
for a whole building, often based on readings of the utility meter where usage is measured. Depending on the project, the
measurement and verification may be required only once, upon installation, based on an analysis of one or more sample
installations, or may be required to be repeated at agreed upon intervals generally over periods of up to 25 years.
Under our contracts, we typically do not take responsibility for a wide variety of factors outside our control and exclude or
adjust for such factors in commitment calculations. These factors include variations in energy prices and utility rates, weather,
facility occupancy schedules, the amount of energy-using equipment in a facility, and failure of the customer to operate or
maintain the project properly. We rely in part on warranties from our equipment suppliers and subcontractors to back-stop the
warranties we provide to our customers and, where appropriate, pass on the warranties to our customers. However, the
warranties we provide to our customers are sometimes broader in scope or longer in duration than the corresponding warranties
we receive from our suppliers and subcontractors, and we bear the risk for any differences, as well as the risk of warranty
default by our suppliers and subcontractors.
Typically, our performance commitments apply to the aggregate overall performance of a project rather than to individual
energy efficiency measures. Therefore, to the extent an individual measure underperforms, it may be offset by other measures
that overperform during the same period. In the event that an energy efficiency project does not perform according to the
agreed-upon specifications, our agreements typically allow us to satisfy our obligation by adjusting or modifying the installed
equipment, installing additional measures to provide substitute energy savings, or paying the customer for lost energy savings
based on the assumed conditions specified in the agreement. However, we may incur additional or increased liabilities or
expenses under our ESPCs in the future. Such liabilities or expenses could be substantial, and they could materially harm our
business, financial condition or operating results. In addition, any disputes with a customer over the extent to which we bear
responsibility to improve performance or make payments to the customer may diminish our prospects for future business from
that customer or damage our reputation in the marketplace.
We may assume responsibility under customer contracts for factors outside our control, including, in connection with some
customer projects, the risk that fuel prices will increase.
We typically do not take responsibility under our contracts for a wide variety of factors outside our control. We have,
however, in a limited number of contracts assumed some level of risk and responsibility for certain factors — sometimes only
to the extent that variations exceed specified thresholds — and may also do so under certain contracts in the future, particularly
in our contracts for renewable energy projects. For example, under a contract for the construction and operation of a
12 cogeneration facility at the U.S. Department of Energy Savannah River Site in South Carolina, a subsidiary of ours is exposed
to the risk that the price of the biomass that will be used to fuel the cogeneration facility may rise during the 19-year
performance period of the contract. Several provisions in that contract mitigate the price risk. In addition, although we typically
structure our contracts so that our obligation to supply a customer with LFG, electricity or steam, for example, does not exceed
the quantity produced by the production facility, in some circumstances we may commit to supply a customer with specified
minimum quantities based on our projections of the facility’s production capacity. In such circumstances, if we are unable to
meet such commitments, we may be required to incur additional costs or face penalties. Despite the steps we have taken to
mitigate risks under these and other contracts, such steps may not be sufficient to avoid the need to incur increased costs to
satisfy our commitments, and such costs could be material. Increased costs that we are unable to pass through to our customers
could have a material adverse effect on our operating results.
Our business depends on experienced and skilled personnel and substantial specialty subcontractor resources, and if we lose
key personnel or if we are unable to attract and integrate additional skilled personnel, it will be more difficult for us to
manage our business and complete projects.
The success of our business and construction projects depend in large part on the skill of our personnel and on trade labor
resources, including with certain specialty subcontractor skills. Competition for personnel, particularly those with expertise in
the energy services and renewable energy industries, is high. In the event we are unable to attract, hire and retain the requisite
personnel and subcontractors, we may experience delays in completing projects in accordance with project schedules and
budgets. Further, any increase in demand for personnel and specialty subcontractors may result in higher costs, causing us to
exceed the budget on a project. Either of these circumstances may have an adverse effect on our business, financial condition
and operating results, harm our reputation among and relationships with our customers and cause us to curtail our pursuit of
new projects.
Our future success is particularly dependent on the vision, skills, experience and effort of our senior management team,
including our executive officers and our founder, principal stockholder, president and chief executive officer, George P.
Sakellaris. If we were to lose the services of any of our executive officers or key employees, our ability to effectively manage
our operations and implement our strategy could be harmed and our business may suffer.
If we cannot obtain surety bonds and letters of credit, our ability to operate may be restricted.
Federal and state laws require us to secure the performance of certain long-term obligations through surety bonds and
letters of credit. In addition, we are occasionally required to provide bid bonds or performance bonds to secure our
performance under energy efficiency contracts. In the future, we may have difficulty procuring or maintaining surety bonds or
letters of credit, and obtaining them may become more expensive, require us to post cash collateral or otherwise involve
unfavorable terms. Because we are sometimes required to have performance bonds or letters of credit in place before projects
can commence or continue, our failure to obtain or maintain those bonds and letters of credit would adversely affect our ability
to begin and complete projects, and thus could have a material adverse effect on our business, financial condition and operating
results.
We operate in a highly competitive industry, and our current or future competitors may be able to compete more effectively
than we do, which could have a material adverse effect on our business, revenues, growth rates and market share.
Our industry is highly competitive, with many companies of varying size and business models, many of which have their
own proprietary technologies, competing for the same business as we do. Many of our competitors have longer operating
histories and greater resources than us, and could focus their substantial financial resources to develop a competitive advantage.
Our competitors may also offer energy solutions at prices below cost, devote significant sales forces to competing with us or
attempt to recruit our key personnel by increasing compensation, any of which could improve their competitive positions. Any
of these competitive factors could make it more difficult for us to attract and retain customers, cause us to lower our prices in
order to compete, and reduce our market share and revenues, any of which could have a material adverse effect on our financial
condition and operating results. We can provide no assurance that we will continue to effectively compete against our current
competitors or additional companies that may enter our markets.
In addition, we may also face competition based on technological developments that reduce demand for electricity, increase
power supplies through existing infrastructure or that otherwise compete with our products and services. We also encounter
competition in the form of potential customers electing to develop solutions or perform services internally rather than engaging
an outside provider such as us.
13 We may be unable to complete or operate our projects on a profitable basis or as we have committed to our customers.
Development, installation and construction of our energy efficiency and renewable energy projects, and operation of our
renewable energy projects, entails many risks, including:
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failure to receive critical components and equipment that meet our design specifications and can be delivered on
schedule;
failure to obtain all necessary rights to land access and use;
failure to receive quality and timely performance of third-party services;
increases in the cost of labor, equipment and commodities needed to construct or operate projects;
permitting and other regulatory issues, license revocation and changes in legal requirements;
shortages of equipment or skilled labor;
unforeseen engineering problems;
failure of a customer to accept or pay for renewable energy that we supply;
weather interferences, catastrophic events including fires, explosions, earthquakes, droughts and acts of terrorism; and
accidents involving personal injury or the loss of life;
labor disputes and work stoppages;
• mishandling of hazardous substances and waste; and
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other events outside of our control.
Any of these factors could give rise to construction delays and construction and other costs in excess of our expectations.
This could prevent us from completing construction of our projects, cause defaults under our financing agreements or under
contracts that require completion of project construction by a certain time, cause projects to be unprofitable for us, or otherwise
impair our business, financial condition and operating results.
Our small-scale renewable energy plants may not generate expected levels of output.
The small-scale renewable energy plants that we construct and own are subject to various operating risks that may cause
them to generate less than expected amounts of processed LFG, electricity or thermal energy. These risks include a failure or
degradation of our, our customers’ or utilities’ equipment; an inability to find suitable replacement equipment or parts; less than
expected supply of the plant’s source of renewable energy, such as LFG or biomass; or a faster than expected diminishment of
such supply. Any extended interruption in the plant’s operation, or failure of the plant for any reason to generate the expected
amount of output, could have a material adverse effect on our business and operating results. In addition, we have in the past,
and could in the future, incur material asset impairment charges if any of our renewable energy plants incurs operational issues
that indicate that our expected future cash flows from the plant are less than its carrying value. Any such impairment charge
could have a material adverse effect on our operating results in the period in which the charge is recorded.
We have not entered into long-term offtake agreements for a portion of the output from our small-scale renewable energy
plants and a portion of the related RINs are not subject to long term contracts.
We have not entered into long-term offtake agreements for a portion of the output from our small-scale renewable energy
plants, particularly LFG plants, and we are required to sell the processed LFG or electricity produced by the facility at
wholesale prices, which are exposed to market fluctuations and risks. Similarly, we have not entered into long-term agreements
with respect to the RINs for which the production and sale of such biofuel may qualify. The failure to sell such processed LFG,
electricity or the related RINs at a favorable price, or at all could have a material adverse effect on our business and operating
results.
We may not be able to replace expiring offtake agreements with contracts on similar terms. If we are unable to replace an
expired offtake agreement with an acceptable new contract, we may be required to remove the small-scale renewable energy
plant from the site or, alternatively, we may sell the assets to the customer.
14 We may not be able to replace an expiring offtake agreement with a contract on equivalent terms and conditions, including
at prices that permit operation of the related facility on a profitable basis. If we are unable to replace an expiring offtake
agreement with an acceptable new revenue contract, the affected site may temporarily or permanently cease operations or we
may be required to sell the power produced by the facility at wholesale prices which are exposed to market fluctuations and
risks. In the case of a solar photovoltaic installation that ceases operations, the offtake agreement terms generally require that
we remove the assets, including fixing or reimbursing the site owner for any damages caused by the assets or the removal of
such assets. Alternatively, we may agree to sell the assets to the site owner, but the terms and conditions, including price, that
we would receive in any sale, and the sale price may not be sufficient to replace the revenue previously generated by the small-
scale renewable energy plant.
We plan to expand our business in part through future acquisitions, but we may not be able to identify or complete suitable
acquisitions.
Historically, acquisitions have been a significant part of our growth strategy. We plan to continue to use acquisitions of
companies or assets to expand our project skill-sets and capabilities, expand our geographic markets, add experienced
management, increase our product and service offerings and add to our energy producing asset portfolio. However, we may be
unable to implement this growth strategy if we cannot identify suitable acquisition candidates, reach agreement with acquisition
targets on acceptable terms or arrange required financing for acquisitions on acceptable terms. In addition, the time and effort
involved in attempting to identify acquisition candidates and consummate acquisitions may divert the attention and efforts of
members of our management from the operations of our company.
Any future acquisitions that we may make could disrupt our business, cause dilution to our stockholders and harm our
business, financial condition or operating results.
If we are successful in consummating acquisitions, those acquisitions could subject us to a number of risks, including:
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the purchase price we pay could significantly deplete our cash reserves or result in dilution to our existing
stockholders;
we may find that the acquired company or assets do not improve our customer offerings or market position as planned;
we may have difficulty integrating the operations and personnel of the acquired company;
key personnel and customers of the acquired company may terminate their relationships with the acquired company as
a result of the acquisition;
we may experience additional financial and accounting challenges and complexities in areas such as tax planning and
financial reporting;
we may incur additional costs and expenses related to complying with additional laws, rules or regulations in new
jurisdictions;
we may assume or be held liable for risks and liabilities (including for environmental-related costs) as a result of our
acquisitions, some of which we may not discover during our due diligence or adequately adjust for in our acquisition
arrangements;
our ongoing business and management’s attention may be disrupted or diverted by transition or integration issues and
the complexity of managing geographically or culturally diverse enterprises;
we may incur one-time write-offs or restructuring charges in connection with the acquisition;
we may acquire goodwill and other intangible assets that are subject to amortization or impairment tests, which could
result in future charges to earnings; and
we may not be able to realize the cost savings or other financial benefits we anticipated.
These factors could have a material adverse effect on our business, financial condition and operating results.
We may be required to write-off or impair capitalized costs or intangible assets in the future, or we may incur restructuring
costs or other charges, each of which could harm our earnings.
15 In accordance with generally accepted accounting principles in the United States, we capitalize certain expenditures and
advances relating to our acquisitions, pending acquisitions, project development costs, interest costs related to project financing
and certain energy assets. In addition, we have considerable unamortized assets. From time to time in future periods, we may be
required to incur a charge against earnings in an amount equal to any unamortized capitalized expenditures and advances, net of
any portion thereof that we estimate will be recoverable, through sale or otherwise, relating to: (i) any operation or other asset
that is being sold, permanently shut down, impaired or has not generated or is not expected to generate sufficient cash flow;
(ii) any pending acquisition that is not consummated; (iii) any project that is not expected to be successfully completed; and
(iv) any goodwill or other intangible assets that are determined to be impaired.
In response to such charges and costs and other market factors, we may be required to implement restructuring plans in an
effort to reduce the size and cost of our operations and to better match our resources with our market opportunities. As a result
of such actions, we would expect to incur restructuring expenses and accounting charges which may be material. Several factors
could cause a restructuring to adversely affect our business, financial condition and results of operations. These include
potential disruption of our operations, the development of our small-scale renewable energy projects and other aspects of our
business. Employee morale and productivity could also suffer and result in unintended employee attrition. Any restructuring
would require substantial management time and attention and may divert management from other important work. Moreover,
we could encounter delays in executing any restructuring plans, which could cause further disruption and additional
unanticipated expense.
See also Note 2, “Summary of Significant Accounting Policies” and Note 5, “Goodwill and Intangible Assets”, to our
Consolidated Financial Statements appearing in Item 8 of this Annual Report on Form 10-K.
We need governmental approvals and permits, and we typically must meet specified qualifications, in order to undertake our
energy efficiency projects and construct, own and operate our small-scale renewable energy projects, and any failure to do
so would harm our business.
The design, construction and operation of our energy efficiency and small-scale renewable energy projects require various
governmental approvals and permits, and may be subject to the imposition of related conditions that vary by jurisdiction. In
some cases, these approvals and permits require periodic renewal. We cannot predict whether all permits required for a given
project will be granted or whether the conditions associated with the permits will be achievable. The denial of a permit essential
to a project or the imposition of impractical conditions would impair our ability to develop the project. In addition, we cannot
predict whether the permits will attract significant opposition or whether the permitting process will be lengthened due to
complexities and appeals. Delay in the review and permitting process for a project can impair or delay our ability to develop
that project or increase the cost so substantially that the project is no longer attractive to us. We have experienced delays in
developing our projects due to delays in obtaining permits and may experience delays in the future. If we were to commence
construction in anticipation of obtaining the final, non-appealable permits needed for that project, we would be subject to the
risk of being unable to complete the project if all the permits were not obtained. If this were to occur, we would likely lose a
significant portion of our investment in the project and could incur a loss as a result. Further, the continued operations of our
projects require continuous compliance with permit conditions. This compliance may require capital improvements or result in
reduced operations. Any failure to procure, maintain and comply with necessary permits would adversely affect ongoing
development, construction and continuing operation of our projects.
In addition, the projects we perform for governmental agencies are governed by particular qualification and contracting
regimes. Certain states require qualification with an appropriate state agency as a precondition to performing work or appearing
as a qualified energy service provider for state, county and local agencies within the state. For example, the Commonwealth of
Massachusetts and the states of Colorado and Washington pre-qualify energy service providers and provide contract documents
that serve as the starting point for negotiations with potential governmental clients. Most of the work that we perform for the
federal government is performed under IDIQ agreements between a government agency and us or a subsidiary. These IDIQ
agreements allow us to contract with the relevant agencies to implement energy projects, but no work may be performed unless
we and the agency agree on a task order or delivery order governing the provision of a specific project. The government
agencies enter into contracts for specific projects on a competitive basis. We and our subsidiaries and affiliates are currently
party to an IDIQ agreement with the U.S. Department of Energy expiring in 2022, which may be extended through December
2023. We are also party to similar agreements with other federal agencies, including the U.S. Army Corps of Engineers and the
U.S. General Services Administration. If we are unable to maintain or renew our IDIQ qualification under the U.S. Department
of Energy program for ESPCs, or similar federal or state qualification regimes, our business could be materially harmed.
16 Many of our small-scale renewable energy projects are, and other future projects may be, subject to or affected by U.S.
federal energy regulation or other regulations that govern the operation, ownership and sale of the facility, or the sale of
electricity from the facility.
PUHCA and the FPA regulate public utility holding companies and their subsidiaries and place constraints on the conduct
of their business. The FPA regulates wholesale sales of electricity and the transmission of electricity in interstate commerce by
public utilities. Under PURPA, all of our current small-scale renewable energy projects are small power “qualifying
facilities” (facilities meeting statutory size, fuel and filing requirements) that are exempt from regulations under PUHCA, most
provisions of the FPA and state rate and financial regulation. None of our renewable energy projects are currently subject to rate
regulation for wholesale power sales by the Federal Energy Regulatory Commission (“FERC”) under the FPA, but certain of
our projects that are under construction or development could become subject to such regulation in the future. Also, we may
acquire interests in or develop generating projects that are not qualifying facilities. Non-qualifying facility projects would be
fully subject to FERC corporate and rate regulation, and would be required to obtain FERC acceptance of their rate schedules
for wholesale sales of energy, capacity and ancillary services, which requires substantial disclosures to and discretionary
approvals from FERC. FERC may revoke or revise an entity’s authorization to make wholesale sales at negotiated, or market-
based, rates if FERC determines that we can exercise market power in transmission or generation, create barriers to entry or
engage in abusive affiliate transactions or market manipulation. In addition, many public utilities (including any non-qualifying
facility generator in which we may invest) are subject to FERC reporting requirements that impose administrative burdens and
that, if violated, can expose the company to civil penalties or other risks.
All of our wholesale electric power sales are subject to certain market behavior rules. These rules change from time to
time, by virtue of FERC rulemaking proceedings and FERC-ordered amendments to utilities’ or power pools’ FERC tariffs. If
we are deemed to have violated these rules, we will be subject to potential disgorgement of profits associated with the violation
and/or suspension or revocation of our market-based rate authority, as well as potential criminal and civil penalties. If we were
to lose market-based rate authority for any non-qualifying facility project we may acquire or develop in the future, we would be
required to obtain FERC’s acceptance of a cost-based rate schedule and could become subject to, among other things, the
burdensome accounting, record keeping and reporting requirements that are imposed on public utilities with cost-based rate
schedules. This could have an adverse effect on the rates we charge for power from our projects and our cost of regulatory
compliance.
Wholesale electric power sales are subject to increasing regulation. The terms and conditions for power sales, and the right
to enter and remain in the wholesale electric sector, are subject to FERC oversight. Due to major regulatory restructuring
initiatives at the federal and state levels, the U.S. electric industry has undergone substantial changes over the past decade. We
cannot predict the future design of wholesale power markets or the ultimate effect ongoing regulatory changes will have on our
business. Other proposals to further regulate the sector may be made and legislative or other attention to the electric power
market restructuring process may delay or reverse the movement towards competitive markets.
If we become subject to additional regulation under PUHCA, FPA or other regulatory frameworks, if existing regulatory
requirements become more onerous, or if other material changes to the regulation of the electric power markets take place, our
business, financial condition and operating results could be adversely affected.
Compliance with environmental laws could adversely affect our operating results.
Costs of compliance with federal, state, provincial, local and other foreign existing and future environmental regulations
could adversely affect our cash flow and profitability. We are required to comply with numerous environmental laws and
regulations and to obtain numerous governmental permits in connection with energy efficiency and renewable energy projects,
and we may incur significant additional costs to comply with these requirements. If we fail to comply with these requirements,
we could be subject to civil or criminal liability, damages and fines. Existing environmental regulations could be revised or
reinterpreted and new laws and regulations could be adopted or become applicable to us or our projects, and future changes in
environmental laws and regulations could occur. These factors may materially increase the amount we must invest to bring our
projects into compliance and impose additional expense on our operations.
In addition, private lawsuits or enforcement actions by federal, state, provincial and/or foreign regulatory agencies may
materially increase our costs. Certain environmental laws make us potentially liable on a joint and several basis for the
remediation of contamination at or emanating from properties or facilities we currently or formerly owned or operated or
properties to which we arranged for the disposal of hazardous substances. Such liability is not limited to the cleanup of
contamination we actually caused. Although we seek to obtain indemnities against liabilities relating to historical contamination
17 at the facilities we own or operate, we cannot provide any assurance that we will not incur liability relating to the remediation
of contamination, including contamination we did not cause.
We may not be able to obtain or maintain, from time to time, all required environmental regulatory approvals. A delay in
obtaining any required environmental regulatory approvals or failure to obtain and comply with them could adversely affect our
business and operating results.
International expansion is one of our growth strategies, and international operations will expose us to additional risks that
we do not face in the United States, which could have an adverse effect on our operating results.
We generate a portion of our revenues from operations outside of the United States, mainly in Canada and the United
Kingdom. International expansion is one of our growth strategies, and we expect our revenues and operations outside of the
United States will expand in the future. These operations will be subject to a variety of risks that we do not face in the United
States, and that we may face only to a limited degree in Canada, the United Kingdom and Greece, including:
•
•
•
•
•
•
•
•
•
building and managing highly experienced foreign workforces and overseeing and ensuring the performance of foreign
subcontractors;
increased travel, infrastructure and legal and compliance costs associated with multiple international locations;
additional withholding taxes or other taxes on our foreign income, and tariffs or other restrictions on foreign trade or
investment;
imposition of, or unexpected adverse changes in, foreign laws or regulatory requirements, many of which differ from
those in the United States;
increased exposure to foreign currency exchange rate risk;
longer payment cycles for sales in some foreign countries and potential difficulties in enforcing contracts and
collecting accounts receivable;
difficulties in repatriating overseas earnings;
general economic conditions in the countries in which we operate; and
political unrest, war, incidents of terrorism, or responses to such events.
We also continue to evaluate the potential effect of the United Kingdom’s planned departure from the European Union
(“EU”) (commonly referred to as Brexit) on our business operations and financial results. On January 29, 2020, the European
Parliament approved the U.K.’s withdrawal from the EU. The U.K. officially left the EU on January 31, 2020. Following its
departure, the U.K. entered into a transition period that is scheduled to last until December 31, 2020 during which period of
time the U.K.’s trading relationship with the EU is expected to remain largely the same while the two parties negotiate a trade
agreement as well as other aspects of the U.K.’s relationship with the EU. Brexit could adversely affect European or worldwide
political, regulatory, economic or market conditions and could contribute to instability in global political institutions, regulatory
agencies and financial markets.
Our overall success in international markets will depend, in part, on our ability to succeed in differing legal, regulatory,
economic, social and political conditions. We may not be successful in developing and implementing policies and strategies that
will be effective in managing these risks in each country where we do business. Our failure to manage these risks successfully
could harm our international operations, reduce our international sales and increase our costs, thus adversely affecting our
business, financial condition and operating results.
Changes in utility regulation and tariffs could adversely affect our business.
Our business is affected by regulations and tariffs that govern the activities and rates of utilities. For example, utility
companies are commonly allowed by regulatory authorities to charge fees to some business customers for disconnecting from
the electric grid or for having the capacity to use power from the electric grid for back-up purposes. These fees could increase
the cost to our customers of taking advantage of our services and make them less desirable, thereby harming our business,
financial condition and operating results. Our current generating projects are all operated as qualifying facilities. FERC
regulations under the FPA confer upon these facilities key rights to interconnection with local utilities, and can entitle
qualifying facilities to enter into power purchase agreements with local utilities, from which the qualifying facilities benefit.
Changes to these federal laws and regulations could increase our regulatory burdens and costs, and could reduce our revenues.
18 State regulatory agencies could award renewable energy certificates or credits that our electric generation facilities produce to
our power purchasers, thereby reducing the power sales revenues we otherwise would earn. In addition, modifications to the
pricing policies of utilities could require renewable energy systems to charge lower prices in order to compete with the price of
electricity from the electric grid and may reduce the economic attractiveness of certain energy efficiency measures.
Some of the demand-reduction services we provide for utilities and institutional clients are subject to regulatory tariffs
imposed under federal and state utility laws. In addition, the operation of, and electrical interconnection for, our renewable
energy projects are subject to federal, state or provincial interconnection and federal reliability standards that are also set forth
in utility tariffs. These tariffs specify rules, business practices and economic terms to which we are subject. The tariffs are
drafted by the utilities and approved by the utilities’ state and federal regulatory commissions. These tariffs change frequently
and it is possible that future changes will increase our administrative burden or adversely affect the terms and conditions under
which we render service to our customers.
Our activities and operations are subject to numerous health and safety laws and regulations, and if we violate such
regulations, we could face penalties and fines.
We are subject to numerous health and safety laws and regulations in each of the jurisdictions in which we operate. These
laws and regulations require us to obtain and maintain permits and approvals and implement health and safety programs and
procedures to control risks associated with our projects. Compliance with those laws and regulations can require us to incur
substantial costs. Moreover, if our compliance programs are not successful, we could be subject to penalties or to revocation of
our permits, which may require us to curtail or cease operations of the affected projects. Violations of laws, regulations and
permit requirements may also result in criminal sanctions or injunctions.
Health and safety laws, regulations and permit requirements may change or become more stringent. Any such changes
could require us to incur materially higher costs than we currently have. Our costs of complying with current and future health
and safety laws, regulations and permit requirements, and any liabilities, fines or other sanctions resulting from violations of
them, could adversely affect our business, financial condition and operating results.
We are subject to various privacy and consumer protection laws.
Our privacy policy is posted on our website, and any failure by us or our vendor or other business partners to comply with
it or with federal, state or international privacy, data protection or security laws or regulations could result in regulatory or
litigation-related actions against us, legal liability, fines, damages and other costs. We may also incur substantial expenses and
costs in connection with maintaining compliance with such laws. For example, commencing in May 2018, the General Data
Protection Regulation (the “GDPR”) became fully effective with respect to the processing of personal information collected
from individuals located in the European Union. The GDPR created new compliance obligations and significantly increases
fines for noncompliance. Although we take steps to protect the security of our customers’ personal information, we may be
required to expend significant resources to comply with data breach requirements if third parties improperly obtain and use the
personal information of our customers or we otherwise experience a data loss with respect to customers’ personal information.
A major breach of our network security and systems could have negative consequences for our business and future prospects,
including possible fines, penalties and damages, reduced customer demand for our services, and harm to our reputation and
brand.
If our subsidiaries default on their obligations under their debt instruments, we may need to make payments to lenders to
prevent foreclosure on the collateral securing the debt.
We typically set up subsidiaries to own and finance our renewable energy projects. These subsidiaries incur various types
of debt which can be used to finance one or more projects. This debt is typically structured as non-recourse debt, which means
it is repayable solely from the revenues from the projects financed by the debt and is secured by such projects’ physical assets,
major contracts and cash accounts and a pledge of our equity interests in the subsidiaries involved in the projects. Although our
subsidiary debt is typically non-recourse to Ameresco, if a subsidiary of ours defaults on such obligations, or if one project out
of several financed by a particular subsidiary’s indebtedness encounters difficulties or is terminated, then we may from time to
time determine to provide financial support to the subsidiary in order to maintain rights to the project or otherwise avoid the
adverse consequences of a default. In the event a subsidiary defaults on its indebtedness, its creditors may foreclose on the
collateral securing the indebtedness, which may result in our losing our ownership interest in some or all of the subsidiary’s
assets. The loss of our ownership interest in a subsidiary or some or all of a subsidiary’s assets could have a material adverse
effect on our business, financial condition and operating results.
19 We are exposed to the credit risk of some of our customers.
Most of our revenues are derived under multi-year or long-term contracts with our customers, and our revenues are
therefore dependent to a large extent on the creditworthiness of our customers. During periods of economic downturn, our
exposure to credit risks from our customers increases, and our efforts to monitor and mitigate the associated risks may not be
effective in reducing our credit risks. In the event of non-payment by one or more of our customers, our business, financial
condition and operating results could be adversely affected.
Fluctuations in foreign currency exchange rates can impact our results.
A portion of our total revenues are generated outside of the United States in currencies including Canadian dollars, British
pound sterling and Euros. Changes in exchange rates between the currencies in which we generate revenues, may adversely
affect our operating results.
A failure of our information technology (“IT”) and data security infrastructure could adversely impact our business and
operations.
We rely upon the capacity, reliability and security of our IT and data security infrastructure and our ability to expand and
continually update this infrastructure in response to the changing needs of our business. As we implement new systems, they
may not perform as expected. We also face the challenge of supporting our older systems and implementing necessary
upgrades. If we experience a problem with the functioning of an important IT system or a security breach of our IT systems,
including during system upgrades and/or new system implementations, the resulting disruptions could have an adverse effect on
our business.
We and certain of our third-party vendors receive and store personal information in connection with our human resources
operations and other aspects of our business. Despite our implementation of security measures, our IT systems, like those of
other companies, are vulnerable to damages from computer viruses, natural disasters, unauthorized access, cyber attack and
other similar disruptions, and we have experienced such incidents in the past. Any system failure, accident or security breach
could result in disruptions to our operations. A material network breach in the security of our IT systems could include the theft
of our intellectual property, trade secrets, customer information, human resources information or other confidential matter.
Although past incidents have not had a material impact on our business operations or financial performance, to the extent that
any disruptions or security breach results in a loss or damage to our data, or an inappropriate disclosure of confidential,
proprietary or customer information, it could cause significant damage to our reputation, affect our relationships with our
customers, lead to claims against the Company and ultimately harm our business. In addition, we may be required to incur
significant costs to protect against damage caused by these disruptions or security breaches in the future. See the discussion of
GDPR in the above risk factor “We are subject to various privacy and consumer protection laws” for an example of new
regulations impacting IT risk.
Risks Related to Ownership of Our Class A Common Stock
The trading price of our Class A common stock is volatile.
The trading price of our Class A common stock is volatile and could be subject to wide fluctuations. In addition, if the
stock market in general experiences a significant decline, the trading price of our Class A common stock could decline for
reasons unrelated to our business, financial condition or operating results. Some companies that have had volatile market prices
for their securities have had securities class actions filed against them. If a suit were filed against us, regardless of its merits or
outcome, it would likely result in substantial costs and divert management’s attention and resources. This could have a material
adverse effect on our business, operating results and financial condition.
Holders of our Class A common stock are entitled to one vote per share, and holders of our Class B common stock are
entitled to five votes per share. The lower voting power of our Class A common stock may negatively affect the attractiveness
of our Class A common stock to investors and, as a result, its market value.
We have two classes of common stock: Class A common stock, which is listed on the NYSE and which is entitled to one
vote per share, and Class B common stock, which is not listed on the any security exchange and is entitled to five votes per
share. The difference in the voting power of our Class A and Class B common stock could diminish the market value of our
Class A common stock because of the superior voting rights of our Class B common stock and the power those rights confer.
20 For the foreseeable future, Mr. Sakellaris or his affiliates will be able to control the selection of all members of our board of
directors, as well as virtually every other matter that requires stockholder approval, which will severely limit the ability of
other stockholders to influence corporate matters.
Except in certain limited circumstances required by applicable law, holders of Class A and Class B common stock vote
together as a single class on all matters to be voted on by our stockholders. Mr. Sakellaris, our founder, principal stockholder,
president and chief executive officer, owns all of our Class B common stock, which, together with his Class A common stock,
represents approximately 80% of the combined voting power of our outstanding Class A and Class B common stock. Under our
restated certificate of incorporation, holders of shares of Class B common stock may generally transfer those shares to family
members, including spouses and descendants or the spouses of such descendants, as well as to affiliated entities, without having
the shares automatically convert into shares of Class A common stock. Therefore, Mr. Sakellaris, his affiliates, and his family
members and descendants will, for the foreseeable future, be able to control the outcome of the voting on virtually all matters
requiring stockholder approval, including the election of directors and significant corporate transactions such as an acquisition
of our company, even if they come to own, in the aggregate, as little as 20% of the economic interest of the outstanding shares
of our Class A and Class B common stock. Moreover, these persons may take actions in their own interests that you or our
other stockholders do not view as beneficial.
Though we may repurchase shares of our Class A common stock pursuant to our recently announced share repurchase
program, we are not obligated to do so and if we do, we may purchase only a limited number of shares of Class A common
stock.
On May 5, 2016, we announced a stock repurchase program under which the Company is currently authorized to
repurchase, in the aggregate, up to $17.6 million of our outstanding Class A common stock. However, we are not obligated to
acquire any shares of our Class A common stock, and holders of our Class A common stock should not rely on the share
repurchase program to increase their liquidity. The amount and timing of any share repurchases will depend upon a variety of
factors, including the trading price of our Class A common stock, liquidity, securities laws restrictions, other regulatory
restrictions, potential alternative uses of capital, and market and economic conditions. We intend to purchase through open
market transactions or in privately negotiated transactions, in accordance with applicable securities laws and regulatory
limitations. We may reduce or eliminate our share repurchase program in the future. The reduction or elimination of our share
repurchase program, particularly if we do not repurchase the full number of shares authorized under the program, could
adversely affect the market price of our common stock.
21 Item 1B. Unresolved Staff Comments
None.
Item 2. Properties
Our corporate headquarters is located in Framingham, Massachusetts, where we occupy approximately 26,000 square feet
under a lease expiring on June 30, 2025. We occupy nine regional offices in Phoenix, Arizona; Islandia, New York; Oak Brook,
Illinois; Columbia, Maryland; Charlotte, North Carolina; Knoxville, Tennessee; Tomball, Texas; Spokane, Washington and
Richmond Hill, Ontario, each less than 25,000 square feet, under lease or sublease agreements. In addition, we lease space,
typically less space, for 74 field offices throughout North America and the U.K. We also own 99 small-scale renewable energy
plants throughout North America, which are located on leased sites or sites provided by customers. We expect to add new
facilities and expand existing facilities as we continue to add employees and expand our business into new geographic areas.
Item 3. Legal Proceedings
In the ordinary conduct of our business we are subject to periodic lawsuits, investigations and claims. Although we cannot
predict with certainty the ultimate resolution of such lawsuits, investigations and claims against us, we do not believe that any
currently pending or threatened legal proceedings to which we are a party will have a material adverse effect on our business,
results of operations or financial condition.
For additional information about certain proceedings, please refer to Note 15, “Commitments and Contingencies”, to our
Consolidated Financial Statements included in this report, which is incorporated into this item by reference.
Item 4. Mine Safety Disclosures
Not applicable.
22 PART II
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity
Securities
Our Class A common stock trades on the New York Stock Exchange under the symbol “AMRC”.
As of March 2, 2020, and according to the records of our transfer agent, there were 10 shareholders of record of our Class
A common stock. A substantially greater number of holders of our Class A common stock are “street name” or beneficial
holders, whose shares are held of record by banks, brokers, and other financial institutions.
Our Class B common stock is not publicly traded and is held of record by George P. Sakellaris, our founder, principal
stockholder, president and chief executive officer, as well as the Ameresco 2017 Annuity Trust, of which Mr. Sakellaris is
trustee and the sole beneficiary.
Dividend Policy
We have never declared or paid any cash dividends on our capital stock. We currently intend to retain earnings, if any, to
finance the growth and development of our business and do not expect to pay any cash dividends for the foreseeable future. Our
revolving senior secured credit facility contains provisions that limit our ability to declare and pay cash dividends during the
term of that agreement. Payment of future dividends, if any, will be at the discretion of our board of directors and will depend
on our financial condition, results of operations, capital requirements, restrictions contained in current or future financing
instruments, provisions of applicable law and other factors our board of directors deems relevant.
Stock Performance Graph
The following performance graph and related information shall not be deemed “soliciting material” or to be “filed” with the
SEC, nor shall such information be incorporated by reference into any future filing under the Securities Act of 1933 (the
“Securities Act”) or the Exchange Act, except to the extent that we specifically incorporate it by reference into such filing.
The following graph compares the cumulative total return attained by shareholders on our Class A common stock relative
to the cumulative total returns of the Russell 2000 index and the NASDAQ Clean Edge Green Energy index. An investment of
$100 (with reinvestment of all dividends) is assumed to have been made in our Class A common stock on December 31, 2014,
and in each of the indexes on December 31, 2014 and its relative performance is tracked through December 31, 2019.
COMPARISON OF FIVE-YEAR CUMULATIVE TOTAL RETURN*
Among Ameresco, Inc., the Russell 2000 Index
and the NASDAQ Clean Edge Green Energy Index
*$100 invested on December 31, 2014 in our Class A common stock or December 31, 2014 in respective index, including
reinvestment of dividends. Fiscal year ending December 31, 2019.
23 Ameresco, Inc.. . . . . . . . . . . . . . . . . . . . . . .
Russell 2000 Index . . . . . . . . . . . . . . . . . . .
NASDAQ Clean Edge Green Energy Index
12/31/2013
$100.00
$100.00
$100.00
12/31/2014
$72.46
$104.89
$107.02
12/31/2015
$64.70
$100.26
$114.81
12/31/2016
$56.94
$121.63
$113.17
12/31/2017
$89.03
$139.44
$155.32
12/31/2018
$145.96
$124.09
$140.36
12/31/2019
$250.00
$148.49
$150.90
Shareholder returns over the indicated period should not be considered indicative of future shareholder returns.
Issuer Purchases of Equity Securities
The following table provides information as of and for the quarter ended December 31, 2019 regarding shares of our Class
A common stock that were repurchased under our stock repurchase program authorized by the Board of Directors on April 27,
2016 (the “Repurchase Program”):
Period
Total Number of
Shares Purchased
Average Price Paid
per Share
Total Number of
Shares Purchased as
Part of Publicly
Announced Plans or
Programs
Approximate
Dollar Value of
Shares that May
Yet Be Purchased
Under the Plans
or Programs
October 1, 2019 - October 31, 2019 . . . .
— $
November 1, 2019 - November 30, 2019
December 1, 2019 - December 31, 2019.
300
—
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
300
$
—
13.94
—
13.94
— $
5,907,722
300
—
300
$
5,903,540
5,903,540
5,903,540
Under the Repurchase Program, we are authorized to repurchase up to $17.6 million of our Class A common stock. Stock
repurchases may be made from time to time through the open market and privately negotiated transactions. The amount and
timing of any share repurchases will depend upon a variety of factors, including the trading price of our Class A common stock,
liquidity, securities laws restrictions, other regulatory restrictions, potential alternative uses of capital, and market and
economic conditions. The Repurchase Program may be suspended or terminated at any time without prior notice, and has no
expiration date.
Item 6. Selected Financial Data
You should read the following selected consolidated financial data in conjunction with Item 7 “Management’s Discussion
and Analysis of Financial Condition and Results of Operations” and our consolidated financial statements and the related notes
appearing in Item 8 “Financial Statements and Supplementary Data” of this Annual Report on Form 10-K. We prepare our
financial statements in conformity with accounting principles generally accepted in the United States of America (“GAAP”).
We derived the consolidated statements of income data for the years ended December 31, 2019, 2018, and 2017 and the
consolidated balance sheets data as of December 31, 2019 and 2018 from our audited consolidated financial statements
appearing in Item 8 of this Annual Report on Form 10-K. We derived the consolidated statements of income data for the years
ended December 31, 2016 and 2015, and the consolidated balance sheets data as of December 31, 2017, 2016, and 2015, from
our audited consolidated financial statements that are not included in this Annual Report on Form 10-K. Our historical results
are not necessarily indicative of the results to be expected in any future period.
24 Year Ended December 31,
2019
2018
2017
2016
2015
(in thousands, except per share data)
Consolidated Statements of Income Data:
Revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 866,933
Cost of revenues . . . . . . . . . . . . . . . . . . . . . . .
698,815
Gross profit . . . . . . . . . . . . . . . . . . . . . . . . .
Selling, general and administrative expenses .
Operating income. . . . . . . . . . . . . . . . . . . . .
Other expenses, net . . . . . . . . . . . . . . . . . . . . .
168,118
116,504
51,614
15,061
(3,748)
36,553
Income before provision for income taxes. .
Income tax (benefit) provision . . . . . . . . . . . .
Net income (loss). . . . . . . . . . . . . . . . . . . . . . .
Net loss attributable to redeemable non-
controlling interests . . . . . . . . . . . . . . . . . . . . .
Net income attributable to common
shareholders. . . . . . . . . . . . . . . . . . . . . . . . . . . $ 44,436
Net income per share attributable to common
shareholders:
40,301
4,135
$ 787,138
$ 717,152
$ 651,227
$ 630,832
613,526
173,612
114,513
59,099
16,709
42,390
4,813
37,577
572,994
144,158
107,570
36,588
7,871
28,717
(4,791)
33,508
516,883
134,344
110,568
23,776
7,409
16,367
4,370
11,997
513,768
117,064
110,007
7,057
6,765
292
4,976
(4,684)
407
3,983
35
5,528
$ 37,984
$ 37,491
$ 12,032
$
844
Basic. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
0.95
0.93
$
$
0.83
0.81
$
$
0.82
0.82
$
$
0.26
0.26
$
$
0.02
0.02
Weighted average common shares
outstanding:
Basic. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
46,586
47,774
45,729
46,831
45,509
45,748
46,409
46,493
46,494
47,665
2019
2018
As of December 31,
2017
(in thousands)
2016
2015
Consolidated Balance Sheets Data:
Cash and cash equivalents . . . . . . . . . . . . . . . . . . . $
Current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Federal ESPC receivable(1). . . . . . . . . . . . . . . . . . .
Energy assets, net . . . . . . . . . . . . . . . . . . . . . . . . . .
Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term debt, less current portion . . . . . . . . . . .
Federal ESPC liabilities(1) . . . . . . . . . . . . . . . . . . .
Total stockholders’ equity . . . . . . . . . . . . . . . . . . . $
33,223
$
61,397
$
24,262
$
20,607
$
21,645
425,192
230,616
579,461
310,969
293,998
459,952
1,374,013
1,161,634
336,647
266,181
245,037
222,630
219,162
288,047
287,078
248,917
356,443
983,951
202,142
173,237
235,088
226,061
158,209
319,758
797,281
190,602
140,593
133,003
263,698
125,804
244,309
723,440
179,723
100,490
122,040
428,856
$
376,875
$
336,620
$
294,306
$
287,409
(1) Federal ESPC receivable represents the amount to be paid by various federal government agencies for work performed and earned
by the Company under specific ESPCs. The Company assigns certain of its rights to receive those payments to third-party investors
that provide construction and permanent financing for such contracts. Federal ESPC liabilities represent the advances received from
third party investors under agreements to finance certain energy savings performance contract projects with various federal
government agencies. Upon completion and acceptance of the project by the government, typically within 24 - 36 months of
25
construction commencement, the ESPC receivable from the Government and corresponding related ESPC liability is eliminated
from our consolidated balance sheets. Until recourse to us ceases for the ESPC receivables transferred to the investor, upon final
acceptance of the work by the Government customer, we remain the primary obligor for financing received.
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
You should read the following discussion and analysis of our financial condition and results of operations together with
our consolidated financial statements and the related notes and other financial information included in Item 8 of this Annual
Report on Form 10-K. Some of the information contained in this discussion and analysis or set forth elsewhere in this Report,
including information with respect to our plans and strategy for our business and related financing, includes forward-looking
statements that involve risks and uncertainties. You should review the “Risk Factors” included in Item 1A of this Annual Report
on Form 10-K for a discussion of important factors that could cause actual results to differ materially from the results
described in or implied by the forward-looking statements contained in the following discussion and analysis.
Overview
Ameresco is a leading provider of energy efficiency solutions for facilities throughout North America and Europe. We
provide solutions that enable customers to reduce their energy consumption, lower their operating and maintenance costs and
realize environmental benefits. Our comprehensive set of services includes upgrades to a facility’s energy infrastructure and the
construction and operation of small-scale renewable energy plants.
In addition to organic growth, strategic acquisitions of complementary businesses and assets have been an important part of
our historical development. Since inception, we have completed numerous acquisitions, which have enabled us to broaden our
service offerings and expand our geographical reach.
Energy Savings Performance and Energy Supply Contracts
For our energy efficiency projects, we typically enter into ESPCs, under which we agree to develop, design, engineer and
construct a project and also commit that the project will satisfy agreed-upon performance standards that vary from project to
project. These performance commitments are typically based on the design, capacity, efficiency or operation of the specific
equipment and systems we install. Our commitments generally fall into three categories: pre-agreed, equipment-level and whole
building-level. Under a pre-agreed energy reduction commitment, our customer reviews the project design in advance and
agrees that, upon or shortly after completion of installation of the specified equipment comprising the project, the commitment
will have been met. Under an equipment-level commitment, we commit to a level of energy use reduction based on the
difference in use measured first with the existing equipment and then with the replacement equipment. A whole building-level
commitment requires demonstration of energy usage reduction for a whole building, often based on readings of the utility meter
where usage is measured. Depending on the project, the measurement and demonstration may be required only once, upon
installation, based on an analysis of one or more sample installations, or may be required to be repeated at agreed upon intervals
generally over up to 25 years.
Under our contracts, we typically do not take responsibility for a wide variety of factors outside of our control and exclude
or adjust for such factors in commitment calculations. These factors include variations in energy prices and utility rates,
weather, facility occupancy schedules, the amount of energy-using equipment in a facility and the failure of the customer to
operate or maintain the project properly. Typically, our performance commitments apply to the aggregate overall performance
of a project rather than to individual energy efficiency measures. Therefore, to the extent an individual measure underperforms,
it may be offset by other measures that overperform during the same period. In the event that an energy efficiency project does
not perform according to the agreed-upon specifications, our agreements typically allow us to satisfy our obligation by
adjusting or modifying the installed equipment, installing additional measures to provide substitute energy savings or paying
the customer for lost energy savings based on the assumed conditions specified in the agreement. Many of our equipment
supply, local design and installation subcontracts contain provisions that enable us to seek recourse against our vendors or
subcontractors if there is a deficiency in our energy reduction commitment. See “We may have liability to our customers under
our ESPCs if our projects fail to deliver the energy use reductions to which we are committed under the contract” in Item 1A,
Risk Factors in this Annual Report on Form 10-K.
Payments by the federal government for energy efficiency measures are based on the services provided and the products
installed, but are limited to the savings derived from such measures, calculated in accordance with federal regulatory guidelines
and the specific contract’s terms. The savings are typically determined by comparing energy use and other costs before and after
26 the installation of the energy efficiency measures, adjusted for changes that affect energy use and other costs but are not caused
by the energy efficiency measures.
For projects involving the construction of a small-scale renewable energy plant that we own and operate, we generally
enter into long-term contracts to supply the electricity, processed LFG, heat or cooling generated by the plant to the customer,
which is typically a utility, municipality, industrial facility or other large purchaser of energy. The rights to use the site for the
plant and purchase of renewable fuel for the plant are also obtained by us under long-term agreements with terms at least as
long as the associated output supply agreement. Our supply agreements typically provide for fixed prices or prices that escalate
at a fixed rate or vary based on a market benchmark. See “We may assume responsibility under customer contracts for factors
outside our control, including, in connection with some customer projects, the risk that fuel prices will increase” in reference
Item 1A, Risk Factors in this Annual Report on Form 10-K.
Project Financing
To finance projects with federal governmental agencies, we typically sell to third-party lenders our right to receive a
portion of the long-term payments from the customer arising out of the project for a purchase price reflecting a discount to the
aggregate amount due from the customer. The purchase price is generally advanced to us over the implementation period based
on completed work or a schedule predetermined to coincide with the construction of the project. Under the terms of these
financing arrangements, we are required to complete the construction or installation of the project in accordance with the
contract with our customer, and the liability remains on our consolidated balance sheets until the completed project is accepted
by the customer. Once the completed project is accepted by the customer, the financing is treated as a true sale and the related
receivable and financing liability are removed from our consolidated balance sheets.
Institutional customers, such as state, provincial and local governments, schools and public housing authorities, typically
finance their energy efficiency and renewable energy projects through either tax-exempt leases or issuances of municipal bonds.
We assist in the structuring of such third-party financing.
In some instances, customers prefer that we retain ownership of the renewable energy plants and related energy assets that
we construct for them. In these projects, we typically enter into a long-term supply agreement to furnish electricity, gas, heat or
cooling to the customer’s facility. To finance the significant upfront capital costs required to develop and construct the plant, we
rely either on our internal cash flow or, in some cases, third-party debt. For project financing by third-party lenders, we
typically establish a separate subsidiary, usually a limited liability company, to own the energy assets and related contracts. The
subsidiary contracts with us for construction and operation of the project and enters into a financing agreement directly with the
lenders. Additionally, we will provide assurance to the lender that the project will achieve commercial operation. Although the
financing is secured by the assets of the subsidiary and a pledge of our equity interests in the subsidiary, and is non-recourse to
Ameresco, Inc., we may from time to time determine to provide financial support to the subsidiary in order to maintain rights to
the project or otherwise avoid the adverse consequences of a default. The amount of such financing is included on our
consolidated balance sheets.
Effects of Seasonality
We are subject to seasonal fluctuations and construction cycles, particularly in climates that experience colder weather
during the winter months, such as the northern United States and Canada, or at educational institutions, where large projects are
typically carried out during summer months when their facilities are unoccupied. In addition, government customers, many of
which have fiscal years that do not coincide with ours, typically follow annual procurement cycles and appropriate funds on a
fiscal-year basis even though contract performance may take more than one year. Further, government contracting cycles can be
affected by the timing of, and delays in, the legislative process related to government programs and incentives that help drive
demand for energy efficiency and renewable energy projects. As a result, our revenues and operating income in the third and
fourth quarter are typically higher, and our revenues and operating income in the first quarter are typically lower, than in other
quarters of the year. As a result of such fluctuations, we may occasionally experience declines in revenues or earnings as
compared to the immediately preceding quarter, and comparisons of our operating results on a period-to-period basis may not
be meaningful.
Our annual and quarterly financial results are also subject to significant fluctuations as a result of other factors, many of
which are outside our control. See “Our business is affected by seasonal trends and construction cycles, and these trends and
cycles could have an adverse effect on our operating results” in Item 1A, Risk Factors in this Annual Report on Form 10-K.
Backlog and Awarded Projects
27 Total construction backlog represents projects that are active within our ESPC sales cycle. Our sales cycle begins with the
initial contact with the customer and ends, when successful, with a signed contract, also referred to as fully-contracted backlog.
Our sales cycle recently has been averaging 18 to 42 months. Awarded backlog is created when a potential customer awards a
project to Ameresco following a request for proposal. Once a project is awarded but not yet contracted, we typically conduct a
detailed energy audit to determine the scope of the project as well as identify the savings that may be expected to be generated
from upgrading the customer’s energy infrastructure. At this point, we also determine the subcontractor, what equipment will be
used, and assist in arranging for third party financing, as applicable. Recently, awarded projects have been taking an average of
12 to 24 months to result in a signed contract and convert to fully-contracted backlog. It may take longer, however, depending
upon the size and complexity of the project. Historically, approximately 90% of our awarded backlog projects have resulted in a
signed contract. After the customer and Ameresco agree to the terms of the contract and the contract becomes executed, the
project moves to fully-contracted backlog. The contracts reflected in our fully-contracted backlog typically have a construction
period of 12 to 36 months and we typically expect to recognize revenue for such contracts over the same period. Fully-
contracted backlog begins converting into revenues generated from backlog over time using cost based input methods once
construction has commenced. See “We may not recognize all revenues from our backlog or receive all payments anticipated
under awarded projects and customer contracts” and “In order to secure contracts for new projects, we typically face a long and
variable selling cycle that requires significant resource commitments and requires a long lead time before we realize revenues”
in Item 1A, Risk Factors in our Annual Report on Form 10-K.
As of December 31, 2019, we had fully-contracted backlog of approximately $1,107.6 million in expected future revenues
under signed customer contracts for the installation or construction of projects. We also had been awarded projects for which
we had not yet signed customer contracts with estimated total future revenues of an additional $1,160.4 million. As of
December 31, 2018, we had fully-contracted backlog of approximately $726.6 million in future revenues under signed customer
contracts for the installation or construction of projects. We also had been awarded projects for which we had not yet signed
customer contracts with estimated total future revenues of an additional $1,241.4 million.
We define our 12-month backlog as the estimated amount of revenues that we expect to recognize in the next twelve
months from our fully-contracted backlog. As of December 31, 2019 and 2018, our 12-month backlog was $564.4 million and
$360.5 million, respectively.
As of December 31, 2019, we had O&M backlog of approximately $1,142.3 million in expected future revenues under
signed multi-year customer contracts for the delivery of O&M services. As of December 31, 2018, we had O&M backlog of
approximately $934.2 million in expected future revenues under signed multi-year customer contracts for the delivery of O&M
services.
Assets in development, which represents the potential design/build project value of small-scale renewable energy plants
that have been awarded or for which we have secured development rights, was approximately $681.0 million and $424.7
million as of December 31, 2019 and 2018, respectively.
Financial Operations Overview
Revenues
We derive revenues principally from energy efficiency projects, which entails the design, engineering and installation of
equipment and other measures that incorporate a range of innovative technology and techniques to improve the efficiency and
control the operation of a facility’s energy infrastructure; this can include designing and constructing for a customer a central
plant or cogeneration system providing power, heat and/or cooling to a building, or other small-scale plant that produces
electricity, gas, heat or cooling from renewable sources of energy. We also derive revenue from: long-term O&M contracts;
energy supply contracts for renewable energy operating assets that we own; integrated-PV; and consulting and enterprise energy
management services.
Historically, including for the years ended December 31, 2019, and 2018, approximately 75% of our revenues have been
derived from federal, state, provincial or local government entities, including public housing authorities and public universities.
Cost of Revenues and Gross Margin
Cost of revenues include the cost of labor, materials, equipment, subcontracting and outside engineering that are required
for the development and installation of our projects, as well as pre-construction costs, sales incentives, associated travel,
inventory obsolescence charges, amortization of intangible assets related to customer contracts, and, if applicable, costs of
28 procuring financing. A majority of our contracts have fixed price terms; however, in some cases we negotiate protections, such
as a cost-plus structure, to mitigate the risk of rising prices for materials, services and equipment.
Cost of revenues also include costs for the small-scale renewable energy plants that we own, including the cost of fuel (if
any) and depreciation charges.
As a result of certain acquisitions, we have intangible assets related to customer contracts; these are amortized over a
period of approximately one to eight years from the respective date of acquisition. This amortization is recorded as a cost of
revenues in the consolidated statements of income. Amortization expense for the year ended December 31, 2019 related to
customer contracts was not significant.
Gross margin, which is gross profit as a percent of revenues, is affected by a number of factors, including the type of
services performed. Renewable energy projects that we own and operate typically have higher margins than energy efficiency
projects, and revenue in the United States typically have higher margins than in Canada due to the typical mix of products and
services that we sell there. In addition, gross margin frequently varies across the construction period of a project. Our expected
gross margin on, and expected revenues for, a project are based on budgeted costs. In some cases, actual costs incurred, or
expected to be incurred, exceed the budgeted costs. In this case, we will adjust the revenue accordingly as a result of a slower
progress-towards-completion estimate on a lower project gross margin estimate. From time to time, a portion of the
contingencies reflected in budgeted costs are not incurred due to strong execution. In that case, and generally at or near project
completion, we recognize revenues for which there is no further corresponding cost of revenues. As a result, gross margin tends
to be backloaded for projects with strong execution; this explains the gross margin improvement that occurs from time to time
at project closeout.
Selling, General and Administrative Expenses
Selling, general and administrative expenses include salaries and benefits, project development costs, and general and
administrative expenses not directly related to the development or installation of projects.
Salaries and benefits. Salaries and benefits consist primarily of expenses for personnel not directly engaged in specific
project or revenue generating activity. These expenses include the time of executive management, legal, finance, accounting,
human resources, information technology and other staff not utilized in a particular project. We employ a comprehensive time
card system which creates a contemporaneous record of the actual time by employees on project activity.
Project development costs. Project development costs consist primarily of sales, engineering, legal, finance and third-party
expenses directly related to the development of a specific customer opportunity. This also includes associated travel and
marketing expenses.
General and administrative expenses. These expenses consist primarily of rents and occupancy, professional services,
insurance, unallocated travel expenses, telecommunications, office expenses, depreciation and amortization of intangible assets
not related to customer contracts. Professional services consist principally of recruiting costs, external legal, audit, tax and other
consulting services. For the years ended December 31, 2019 and 2018, we recorded amortization expense of $0.9 million and
$1.1 million, respectively, related to customer relationships, non-compete agreements, technology and trade names.
Other Expenses, Net
Other expenses, net, includes gains and losses from derivatives, interest income and expenses, amortization of deferred
financing costs, net, and foreign currency transaction gains and losses. Interest expense will vary periodically depending on the
amounts drawn on our revolving senior secured credit facility and the prevailing short-term interest rates.
Provision or Benefit for Income Taxes
The provision or benefit for income taxes is based on various rates set by federal and local authorities and is affected by
permanent and temporary differences between financial accounting and tax reporting requirements.
Critical Accounting Policies and Estimates
This discussion and analysis of our financial condition and results of operations is based upon our consolidated financial
statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The
preparation of these consolidated financial statements requires management to make estimates and assumptions that affect the
reported amounts of assets, liabilities, revenue, expense and related disclosures. The most significant estimates with regard to
these consolidated financial statements relate to our estimates of final construction contract profit in accordance with
29 accounting for long-term contracts under the revenue recognition requirements of contracts with our customers, allowance for
doubtful accounts, inventory reserves, realization of project development costs, leases, fair value of derivative financial
instruments, accounting for business acquisitions, stock-based awards, impairment of long-lived assets and goodwill, income
taxes, self insurance reserves and potential liability in conjunction with certain commitments and contingencies. Actual results
could differ from those estimates.
Such estimates and assumptions are based on historical experience and on various other factors that management believes
to be reasonable under the circumstances. Estimates and assumptions are made on an ongoing basis, and accordingly, the actual
results may differ from these estimates under different assumptions or conditions.
The following are critical accounting policies that, among others, affect our more significant judgments and estimates used
in the preparation of our consolidated financial statements.
Revenue Recognition
On January 1, 2018, we adopted ASU 2014-09, “Revenue from Contracts with Customers” (Topic 606) using the modified
retrospective method applied to those contracts which were not completed as of December 31, 2017. Results for reporting
periods beginning January 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to
be reported under the accounting standards in effect for the prior periods. We recorded an adjustment to retained earnings on
January 1, 2018 due to the cumulative impact of adopting Topic 606. See Note 3 "Revenue from Contracts with Customers" for
the required disclosures related to the impact of adopting this standard and a discussion of updated policies related to revenue
recognition discussed below.
We derive revenues from energy efficiency and renewable energy products and services. Energy efficiency products and
services include the design, engineering, and installation of equipment and other measures to improve the efficiency, and
control the operation, of a facility’s energy infrastructure. Renewable energy products and services include the construction of
small-scale plants that produce electricity, gas, heat or cooling from renewable sources of energy, the sale of such electricity,
gas, heat or cooling from plants that we own, and the sale and installation of solar energy products and systems. Below is a
description of our primary lines of business.
Projects - Our principal service relates to energy efficiency projects, which entails the design, engineering and installation
of, and assisting with the arranging of financing for an ever-increasing array of innovative technologies and techniques to
improve the energy efficiency, and control the operation, of a building’s energy and water consuming systems. In certain
projects, we also designed and constructed for a customer a central plant or cogeneration system providing power, heat and/or
cooling to a building, or a small-scale plant that produces electricity, gas, heat or cooling from renewable sources of energy.
Under Topic 606 requirements, we recognize revenue from the installation or construction of projects over time using the
cost-based input method. We use the total costs incurred on the project relative to the total expected costs to satisfy the
performance obligation.
When the estimate on a contract indicates a loss, or claims against costs incurred reduce the likelihood of recoverability of
such costs, we record the entire estimated loss in the period the loss becomes known.
Operations & Maintenance (“O&M”) - After an energy efficiency or renewable energy project is completed, we often
provide ongoing O&M services under a multi-year contract. These services include operating, maintaining and repairing facility
energy systems such as boilers, chillers and building controls, as well as central power and other small-scale plants. For larger
projects, we frequently maintain staff on-site to perform these services.
Maintenance revenue uses the input method to recognize revenue. In most cases, O&M fees are fixed annual fees. Because
we are on-site to perform O&M services, the services are typically a distinct series of promises, and those services have the
same pattern of transfer to the customer (i.e., evenly over time), we record the revenue on a straight-line basis. Some O&M
service contract fees are billed on time expended. In those cases, revenue is recorded based on the time expended in that month.
Energy Assets - Our service offerings also include the sale of electricity, processed renewable gas fuel, heat or cooling from
the portfolio of assets that we own and operate. We have constructed and are currently designing and constructing a wide range
of renewable energy plants using LFG, wastewater treatment biogas, solar, biomass, other bio-derived fuels, wind and hydro
sources of energy. Most of our renewable energy projects to date have involved the generation of electricity from solar PV and
LFG or the sale of processed LFG. We purchase the LFG that otherwise would be combusted or flared, processes it, and either
sell it or use it in our energy plants. We also design and build, as well as own, operate and maintain, plants that take biogas
30 generated in the anaerobic digesters of wastewater treatment plants and turn it into renewable natural gas that is either used to
generate energy on-site or that can be sold through the nation’s natural gas pipeline grid. Where we own and operate energy
producing assets, we typically enter into a long-term power purchase agreement (“PPA”) for the sale of the energy. Many of our
energy assets also produce environmental attributes, including RECs and RINs. In most cases, we sell these attributes under
separate agreements with third parties other than the PPA customer.
We recognize revenues from the sale and delivery of the energy output from renewable energy plants, over time as
produced and delivered to the customer, in accordance with specific PPA contract terms. Environmental attributes revenue is
recognized at a point in time, when the environmental attributes are transferred to the customer in accordance with the transfer
protocols of the attribute market that we operate in. In those cases where environmental attributes are sold to the same customer
as the energy output, we record revenue monthly for both the energy output and the environmental attributes output, as
generated and delivered to the customer.
Other - Our service and product offerings also include integrated-PV and consulting and enterprise energy management
services.
We recognize revenues from delivery of engineering, consulting services and enterprise energy management services over
time. For the sale of solar materials, revenue is recognized at a point in time when we have transferred physical control of the
asset to the customer upon shipment.
To the extent a contract is deemed to have multiple performance obligations, we allocate the transaction price of the
contract to each performance obligation using its best estimate of the standalone selling price of each distinct good or service in
the contract.
Billings in excess of cost and estimated earnings represents advanced billings on certain construction contracts. Costs and
estimated earnings in excess of billings represent certain amounts under customer contracts that were earned and billable but
not invoiced.
Results for reporting periods beginning January 1, 2018 are presented under Topic 606, while prior period amounts are not
adjusted and continue to be reported under Accounting Standards Codification (“ASC”) 605, Revenue Recognition.
Project Development Costs
We capitalize as project development costs only those costs incurred in connection with the development of energy
efficiency and renewable energy projects, primarily direct labor, interest costs, outside contractor services, consulting fees, legal
fees and associated travel, if incurred after a point in time when the realization of related revenue becomes probable. Project
development costs incurred prior to the probable realization of revenues are expensed as incurred.
Energy Assets
Energy assets consist of costs of materials, direct labor, interest costs, outside contract services, deposits and project
development costs incurred in connection with the construction of small-scale renewable energy plants that we own. These
amounts are capitalized and amortized to cost of revenues in our consolidated statements of income on a straight line basis over
the lives of the related assets or the terms of the related contracts.
We capitalize interest costs relating to construction financing during the period of construction. Capitalized interest is
included in energy assets, net, in our consolidated balance sheets. Capitalized interest is amortized to cost of revenues in our
consolidated statements of income on a straight line basis over the useful life of the associated energy asset. The amount of
interest capitalized for the years ended December 31, 2019 and 2018 was $3.0 million and $3.8 million, respectively.
Routine maintenance costs are expensed in the current year’s consolidated statements of income to the extent that they do
not extend the life of the asset. Major maintenance, upgrades and overhauls are required for certain components of our assets. In
these instances, the costs associated with these upgrades are capitalized and are depreciated over the shorter of the remaining
life of the asset or the period until the next required major maintenance or overhaul.
We evaluate our long-lived assets for impairment as events or changes in circumstances indicate the carrying value of these
assets may not be fully recoverable. Examples of such triggering events applicable to our assets include a significant decrease
in the market price of a long-lived asset or asset group or a current-period operating or cash flow loss combined with a history
of operating or cash flow losses or a projection or forecast that demonstrates continuing losses associated with the use of a long-
lived asset or asset group.
31 We evaluate recoverability of long-lived assets to be held and used by estimating the undiscounted future cash flows
associated with the expected uses and eventual disposition of those assets. When these comparisons indicate that the carrying
value of those assets is greater than the undiscounted cash flows, we recognize an impairment loss for the amount that the
carrying value exceeds the fair value.
From time to time, we have applied for and received cash grant awards from the U.S. Treasury Department (the
“Treasury”) under Section 1603 of the American Recovery and Reinvestment Act of 2009 (the “Act”). The Act authorized the
Treasury to make payments to eligible persons who place in service qualifying renewable energy projects. The grants are paid
in lieu of investment tax credits. All of the cash proceeds from the grants were used and recorded as a reduction in the cost
basis of the applicable energy assets. If we dispose of the property, or the property ceases to qualify as specified energy
property, within five years from the date the property is placed in service, then a prorated portion of the Section 1603 payment
must be repaid.
We last received a Section 1603 grant during the year ended December 31, 2014. No further Section 1603 grant payments
are expected to be received as the program has expired.
For tax purposes, the Section 1603 payments are not included in federal and certain state taxable income and the basis of
the property is reduced by 50% of the payment received. Deferred grant income of $6.1 million and $6.6 million in the
accompanying consolidated balance sheets at December 31, 2019 and 2018, respectively, represents the benefit of the basis
difference to be amortized to income tax expense over the life of the related property.
Leases
We adopted Accounting Standard Update (“ASU”) 2016-02, Leases (Topic 842) as of January 1, 2019 and, along with the
standard, elected to take the practical expedient that the Company will not reassess lease classifications at adoption. Accordingly,
the Company’s sales-leaseback arrangements entered into as of December 31, 2018 will remain under the previous guidance. See
Note 7 and 8 for additional information on these sale-leasebacks.
All significant lease arrangements are recognized at lease commencement. Operating lease right-of-use (“ROU”) assets and
lease liabilities are recognized at commencement. An ROU asset and corresponding lease liability are not recorded for leases with
an initial term of 12 months or less (short-term leases) as the Company recognizes lease expense for these leases as incurred over
the lease term.
ROU assets represent the Company’s right to use an underlying asset during the reasonably certain lease term and lease
liabilities represent the Company’s obligation to make lease payments arising from the lease. The Company’s lease terms may
include options to extend or terminate the lease when it is reasonably certain that the Company will exercise that option. Operating
lease ROU assets and liabilities are recognized at commencement date based on the present value of lease payments over the lease
term. The Company uses its incremental borrowing rate, which is updated annually or when a significant event occurs that would
indicate a significant change in rates, based on the information available at commencement date, in determining the present value
of lease payments. The operating lease ROU asset also includes any lease payments related to initial direct cost and prepayments
and excludes lease incentives. Lease expense is recognized on a straight-line basis over the lease term. The Company has lease
agreements with lease and non-lease components, which are accounted for as a single component. See Note 8 for additional
discussion on the Company’s leases.
Impairment of Goodwill and Intangible Assets
We have classified as goodwill the amounts paid in excess of fair value of the net assets (including tax attributes) of companies
acquired in purchase transactions. We have recorded intangible assets related to customer contracts, customer relationships, non-
compete agreements, trade names and technology, each with defined useful lives. We assess the impairment of goodwill and
intangible assets that have indefinite lives on an annual basis (December 31st) and whenever events or changes in circumstances
indicate that the carrying value of the asset may not be recoverable.
Goodwill is reviewed for impairment annually and whenever events or changes in circumstances indicate that the carrying
value of an asset may not be recoverable. The process of evaluating the potential impairment of goodwill requires significant
judgment. We regularly monitor current business conditions and other factors including, but not limited to, adverse industry or
economic trends, restructuring actions and projections of future results. We estimate the reporting unit’s fair value and compare
it with the carrying value of the reporting unit, including goodwill. If the fair value is greater than the carrying value of its reporting
32 unit, no impairment is recorded. Fair value is determined using both an income approach and a market approach. The estimates
and assumptions used in our calculations include revenue growth rates, expense growth rates, expected capital expenditures to
determine projected cash flows, expected tax rates and an estimated discount rate to determine present value of expected cash
flows. These estimates are based on historical experiences, our projections of future operating activity and our weighted-average
cost of capital.
Acquired intangible assets other than goodwill that are subject to amortization include customer contracts and customer
relationships, as well as software/technology, trade names and non-compete agreements. The intangible assets are amortized over
periods ranging from one to fifteen years from their respective acquisition dates. We evaluate the intangible assets for impairment
consistent with, and part of, their long-lived assets evaluation, as discussed in Energy Assets above.
Impairment of Long-Lived Assets
We use the guidance prescribed in ASC 360, Property, Plant and Equipment, for the proper testing and valuation methodology
to ensure we record any impairment when the carrying amount of a long-lived asset is not recoverable equivalent to an amount
equal to its fair market value.
We review long-lived asset groups for potential impairment whenever events or changes in circumstances indicate that the
carrying amount of the assets may not be fully recoverable or that the useful lives of these assets are no longer appropriate. Examples
of such triggering events applicable to our asset groups include a significant decrease in the market price of a long-lived asset
group or a current-period operating or cash flow loss combined with a history of operating or cash flow losses or a projection or
forecast that demonstrates continuing losses associated with the use of a long-lived asset group, among others.
Should an asset group be identified as potentially impaired based on the defined criteria, an impairment test is performed
that includes a comparison of the estimated undiscounted cash flows of the asset as compared to the recorded value of the asset.
If these estimates or their related assumptions change in the future, an impairment charge may be required against these assets in
the reporting period in which the impairment is determined.
Derivative Financial Instruments
We account for our interest rate swaps and commodity swaps as derivative financial instruments. As required under
Generally Accepted Accounting Principles (“GAAP”), derivatives are carried on our consolidated balance sheets at fair value.
The fair value of our interest rate and commodity swaps are determined based on observable market data in combination with
expected cash flows for each instrument.
We follow the guidance which expands the disclosure requirements for derivative instruments and hedging activities.
In the normal course of business, we utilize derivative contracts as part of our risk management strategy to manage
exposure to market fluctuations in interest rates and natural gas prices. These instruments are subject to various credit and
market risks. Controls and monitoring procedures for these instruments have been established and are routinely reevaluated.
Credit risk represents the potential loss that may occur because a party to a transaction fails to perform according to the terms of
the contract. The measure of credit exposure is the replacement cost of contracts with a positive fair value. We seek to manage
credit risk by entering into financial instrument transactions only through counterparties that we believe to be creditworthy.
Market risk represents the potential loss due to the decrease in the value of a financial instrument caused primarily by changes
in interest rates and natural gas prices. We seek to manage market risk by establishing and monitoring limits on the types and
degree of risk that may be undertaken. As a matter of policy, we do not use derivatives for speculative purposes.
We are exposed to interest rate risk through our borrowing activities. A portion of our project financing includes twelve
credit facilities that utilize a variable rate swap instrument. We are also exposed to commodity price risk through our variable
rate commodity swap instruments. We have two commodity swaps as of December 31, 2019.
In June 2018, the Company entered into a term loan agreement, discussed in Note 9, that contained an interest make-whole
provision. In August 2018, the Company signed a joinder to the above agreement, which added another series of notes to the
term loan that also contained an interest make-whole provision. The Company determined that these provisions fulfill the
requirements of embedded derivative instruments that were required to be bifurcated from the host agreement. The fair value of
these make-whole provisions was determined based on available market data and a with and without model.
33 The following tables present a listing of all our active derivative instruments as of December 31, 2019 ($ in thousands):
Active Interest Rate Swap
Effective Date
Expiration Date
October 2029
June 2033
11-Year, 5.77% Fixed . . . . . . . . . . . . October 2018
15-Year, 5.24% Fixed . . . . . . . . . . . . June 2018
3-Year, 2.46% Fixed . . . . . . . . . . . . . March 2018
10-Year, 4.74% Fixed . . . . . . . . . . . . June 2017
15-Year, 3.26% Fixed . . . . . . . . . . . . February 2023
7-Year, 2.19% Fixed . . . . . . . . . . . . . February 2016
8-Year, 3.70% Fixed . . . . . . . . . . . . . March 2020
8-Year, 3.70% Fixed . . . . . . . . . . . . . March 2020
8-Year, 1.71% Fixed . . . . . . . . . . . . . October 2012
8-Year, 1.71% Fixed . . . . . . . . . . . . . October 2012
15-Year, 5.30% Fixed . . . . . . . . . . . . February 2006
15.5-Year, 5.40% Fixed . . . . . . . . . . September 2008 March 2024
March 2020
March 2020
June 2028
June 2028
December 2020
December 2027
December 2038
February 2021
February 2023
Initial Notional
Amount ($)
Status
$
9,200 Designated
10,000 Designated
17,100 Not Designated
14,100 Designated
14,084 Designated
20,746 Designated
14,643 Designated
10,734 Designated
9,665 Designated
7,085 Designated
3,256 Designated
13,081 Designated
Active Commodity Swap
Effective
Date
1-Year, $2.68 MMBtu Fixed. . . . . . . May 2019
1-Year, $2.70 MMBtu Fixed. . . . . . . May 2020
Expiration
Date
April 2020
April 2021
Initial
Notional
Amount
(Volume)
Commodity
Measurement
Status
437,004 MMBtus
Not Designated
435,810 MMBtus
Not Designated
Other Derivatives
Classification
Effective Date
Expiration Date
Fair Value ($)
Interest make-whole provisions . . . . Liability
June/August
2018
December 2038
$
918
We entered into each of the interest rate and commodity swap contracts as an economic hedge.
We recognize all derivatives in our consolidated financial statements at fair value.
We recognize the fair value of derivative instruments designated as hedges in our consolidated balance sheets and any
changes in the fair value are recorded as adjustments to other comprehensive income if the hedges operate effectively.
Income Taxes
We provide for income taxes based on the liability method. We provide for deferred income taxes based on the expected
future tax consequences of differences between the financial statement basis and the tax basis of assets and liabilities calculated
using the enacted tax rates in effect for the year in which the differences are expected to be reflected in the tax return.
We account for uncertain tax positions using a “more-likely-than-not” threshold for recognizing and resolving uncertain tax
positions. The evaluation of uncertain tax positions is based on factors that include, but are not limited to, changes in tax law,
the measurement of tax positions taken or expected to be taken in tax returns, the effective settlement of matters subject to
audit, new audit activity and changes in facts or circumstances related to a tax position. We evaluate uncertain tax positions on a
quarterly basis and adjust the level of the liability to reflect any subsequent changes in the relevant facts surrounding the
uncertain positions. Our liabilities for an uncertain tax position can be relieved only if the contingency becomes legally
extinguished through either payment to the taxing authority or the expiration of the statute of limitations, the recognition of the
34 benefits associated with the position meet the “more-likely-than-not” threshold or the liability becomes effectively settled
through the examination process. We consider matters to be effectively settled once the taxing authority has completed all of its
required or expected examination procedures, including all appeals and administrative reviews, we have no plans to appeal or
litigate any aspect of the tax position and we believe that it is highly unlikely that the taxing authority would examine or re-
examine the related tax position. We also accrue for potential interest and penalties, related to unrecognized tax benefits in
income tax expense.
We have presented all deferred tax assets and liabilities as noncurrent on our consolidated balance sheets as of
December 31, 2019, and 2018, respectively.
Stock-Based Compensation Expense
Our stock-based compensation expense results from the issuances of shares of restricted common stock and grants of
stock options to employees, directors, outside consultants and others. We recognize the costs associated with option grants
using the fair value recognition provisions of ASC 718, Compensation — Stock Compensation. Generally, ASC 718 requires
the value of all stock-based payments to be recognized in the statement of income based on their estimated fair value at date
of grant amortized over the grants’ respective vesting periods. For the years ended December 31, 2019 and 2018, we
recorded stock-based compensation expense of approximately $1.6 million and $1.3 million, respectively, in connection
with stock-based payment awards. The compensation expense is categorized as a portion of general and administrative
expenses in the accompanying consolidated statements of income. Stock-based compensation expense is also recognized in
association with employee stock purchases related to the Company’s Employee Stock Purchase Plan.
Stock Option Grants
We have granted stock options to certain employees and directors under our 2010 stock incentive plan and at
December 31, 2019, 5,717 shares were available for grant under that plan. We have also granted stock options to certain
employees and directors under our 2000 stock incentive plan; however, we will grant no further stock options or restricted
stock awards under that plan.
Stock options issued under our 2000 stock incentive plan generally expire if not exercised within ten years after the grant
date. Under the terms of our 2010 stock incentive plan, all options expire if not exercised within ten years after the grant date.
During 2011, we began awarding options which typically vest over a five year period on an annual ratable basis. If the
employee ceases to be employed for any reason before vested options have been exercised, the employee generally has three
months to exercise vested options or they are forfeited. Certain option grants have performance conditions that must be
achieved prior to vesting and are expensed based on the expected achievement at each reporting period.
We follow the fair value recognition provisions of ASC 718 requiring that all stock-based payments to employees,
including grants of employee stock options and modifications to existing stock options, be recognized in the consolidated
statements of income based on their fair values, using the prospective-transition method.
We use the Black-Scholes option pricing model to determine the weighted-average fair value of options granted and record
stock-based compensation expense utilizing the straight-line method.
The determination of the fair value of stock-based payment awards utilizing the Black-Scholes model is affected by the
stock price and a number of assumptions, including expected volatility, expected life, risk-free interest rate and expected
dividends. The following table sets forth the significant assumptions used in the model during 2019, 2018 and 2017:
Expected dividend yield . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Risk-free interest rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Expected volatility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Expected life . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2019
—%
Year Ended December 31,
2018
—%
2017
—%
1.60%-2.39%
2.71%-3.00%
1.96%-2.36%
43%-44%
6.5 years
43%-45%
6.5 years
46%
6.5 years
We will continue to use our judgment in evaluating the expected term, volatility and forfeiture rate related to our own
stock-based compensation on a prospective basis, and incorporating these factors into the Black-Scholes pricing model. Higher
volatility and longer expected lives result in an increase to stock-based compensation expense determined at the date of grant.
These expenses will affect our cost of revenues as well as our selling, general and administrative expenses.
35 As of December 31, 2019, we had $9.5 million of total unrecognized stock-based compensation expense related to
employee and director stock options. We expect to recognize this cost over a weighted-average period of 2.7 years after
December 31, 2019. This expense is categorized as a portion of selling, general and administrative expenses in the
accompanying consolidated statements of income.
Recent Accounting Pronouncements
See Note 2 of the “Notes to Consolidated Financial Statements” for a discussion of recent accounting standards.
Results of Operations
On January 1, 2018, the Company adopted new accounting guidance on revenue from contracts with customers, using the
modified retrospective method applied to contracts that were not completed as of January 1, 2018. Results for reporting periods
beginning after January 1, 2018 are presented under that guidance, while prior period amounts are not adjusted and continue to
be reported in accordance with the previous guidance. See Note 3, Revenue From Contracts with Customers, of Notes to
Consolidated Financial Statements for further details.
The following table sets forth certain financial data from the consolidated statements of income expressed as a percentage
of revenues for the periods indicated (in thousands):
Year Ended December 31,
2019
2018
Dollar
Amount
% of
Revenues
Dollar
Amount
% of
Revenues
100.0 % $ 787,138
100.0%
168,118
Revenues. . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 866,933
Cost of revenues . . . . . . . . . . . . . . . . . . . . . . .
698,815
Gross profit . . . . . . . . . . . . . . . . . . . . . . . . .
Selling, general and administrative expenses .
Operating income . . . . . . . . . . . . . . . . . . . .
Other expenses, net. . . . . . . . . . . . . . . . . . . . .
Income before (benefit) provision for income
taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Income tax (benefit) provision . . . . . . . . . . . .
Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Net loss attributable to redeemable non-
controlling interests . . . . . . . . . . . . . . . . . . . . $
116,504
40,301
36,553
15,061
51,614
4,135
(3,748)
80.6 %
19.4 %
13.4 %
6.0 %
1.7 %
4.2 %
(0.4)%
613,526
173,612
114,513
59,099
16,709
42,390
4,813
4.6 % $
37,577
0.5 % $
407
Net income attributable to common
shareholders . . . . . . . . . . . . . . . . . . . . . . . . . . $
44,436
5.1 % $
37,984
Revenues
77.9%
22.1%
14.5%
7.5%
2.1%
5.4%
0.6%
4.8%
0.1%
4.8%
The following table sets forth a comparison of our revenues for the periods indicated (in thousands):
Year Ended December 31,
2018
2019
Dollar
Change
Percentage
Change
Revenues. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
866,933
$
787,138
$
79,795
10.1%
Total revenues increased by $79.8 million, or 10.1%, from 2018 to 2019 primarily due to a $41.1 million increase in
revenues from our U.S. Federal segment, a $30.7 million increase in revenues from our U.S. Regions segment, a $7.0 million
increase from All Other, and a $2.0 million increase in revenues from our Non-solar Distributed Generation (“DG”) segment.
These increases were partially offset by a $1.1 million decrease in revenues from our Canada segment.
36 Cost of Revenues and Gross Margin
The following table sets forth a comparison of our cost of revenues and gross profit for the periods indicated (in
thousands):
Cost of revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Gross margin % . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Year Ended December 31,
2018
2019
613,526
698,815
$
19.4%
22.1%
Dollar
Change
Percentage
Change
$
85,289
13.9%
Cost of revenues. Total cost of revenues increased $85.3 million, or 13.9%, from 2018 to 2019 due primarily to an increase
in project revenues from our U.S. Federal and U.S. Regions segments.
Gross margin. Gross margin decreased from 22.1% in 2018 to 19.4% in 2019. The decrease in gross margin is primarily
due to an increase in lower margin projects in our U.S. Regions and Federal segments and lower margin energy and incentive
revenue in our Non-Solar DG segment.
Selling, General and Administrative Expenses
The following table sets forth a comparison of our selling, general and administrative expenses for the periods indicated (in
thousands):
Year Ended December 31,
2018
2019
Dollar
Change
Percentage
Change
Selling, general and administrative expenses . . . . . . . $
116,504
$
114,513
$
1,991
1.7%
Selling, general and administrative expenses increased $2.0 million or 1.7% to $116.5 million from $114.5 million from
2018 to 2019 primarily due to an increase in salaries and benefits of $4.3 million resulting from increased headcount partially
offset by a gain of $2.2 million recognized on the deconsolidation of a variable interest entity.
Other Expenses, Net
Other expenses, net, includes gains and losses from derivatives transactions, foreign currency transactions, interest
expense, interest income and amortization of deferred financing costs, net. Other expenses, net, decreased from 2018 to 2019 by
$1.6 million primarily due to favorable foreign exchange rate fluctuations realized.
Income Before Taxes
Income before taxes decreased from 2018 to 2019 by $5.8 million primarily due to the reasons described above.
Provision (Benefit) for Income Taxes
The provision (benefit) for income taxes is based on various rates set by federal, state, provincial and local authorities and
is affected by permanent and temporary differences between financial accounting and tax reporting requirements. During 2019,
we recognized an income tax benefit of $(3.7) million, equivalent to an effective tax rate of (10.3)%. The effective tax rate
decreased for 2019 as compared to 2018 primarily due to the availability of Section 179D energy efficiency deduction which
was retroactively extended for 2018 and 2019 on December 20, 2019. During 2018, we recognized an income tax provision of
$4.8 million, equivalent to an effective tax rate of 11.4%.
The principal reasons for the difference between the statutory rate and the estimated annual effective rate for 2019 related
to our recognizing a tax benefit of approximately $29.7 million associated with energy related credits and deductions available
under the U.S. Tax Code for 2019 as well as a deduction available under Section 179D of the Tax Code for 2019 and 2018. In
December 2019, the Code Section 179D Commercial Buildings Energy Efficiency Tax Deduction was retroactively extended
for 2018 and 2019, and through the end of 2020. Because of the timing of the extension the impact of the 2018 Section 179D
deduction was not reflected in the 2018 tax provision but was instead reflected in 2019.
Net Income
Net income increased $2.7 million to a net income of $40.3 million for the twelve months ended December 31, 2019
compared to a net income of $37.6 million for the same period of 2018 for the reasons discussed above. Basic income per
share for the twelve months ended December 31, 2019 was $0.95 per share, an increase of $0.12 per share, compared to the
37 same period of 2018. Diluted income per share for the twelve months ended December 31, 2019 was $0.93 per share, an
increase of $0.12 per share, compared to the same period of 2018.
Business Segment Analysis (in thousands)
We report results under ASC 280, Segment Reporting. Our reportable segments for the year ended December 31, 2019 are
U.S. Regions, U.S. Federal, Canada and Non-Solar Distributed Generation “ Non-Solar DG”. Our U.S. Regions, U.S. Federal
and Canada segments offer energy efficiency products and services, which include: the design, engineering and installation of
equipment and other measures to improve the efficiency and control the operation of a facility’s energy infrastructure;
renewable energy solutions and services, which include the construction of small-scale plants that we own or develop for
customers that produce electricity, gas, heat or cooling from renewable sources of energy; and O&M services. Our Non-Solar
DG segment primarily sells electricity, processed renewable gas fuel, heat or cooling, produced from renewable sources of
energy, other than solar, and generated by small-scale plants that we own. This segment also performs O&M services for
customer-owned small-scale plants. The “All Other” category offers enterprise energy management services, consulting
services and integrated-PV. These segments do not include results of other activities, such as corporate operating expenses not
specifically allocated to the segments.
U.S. Regions
Year Ended December 31,
2018
2019
Dollar
Change
Percentage
Change
Revenues. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Income before taxes . . . . . . . . . . . . . . . . . . . . . . . . . . $
365,060
15,925
$
$
334,344
20,543
$
$
30,716
(4,618)
9.2 %
(22.5)%
Revenues for the U.S. Regions segment increased by $30.7 million, or 9.2%, to $365.1 million for the twelve months
ended December 31, 2019 compared to the same period of 2018 primarily due to an increase in project revenues attributable to
the quantity of projects and timing of revenue recognized as a result of the phase of active projects versus the prior year.
Income before taxes for the U.S. Regions segment decreased by $4.6 million, or 22.5%, for the twelve months ended
December 31, 2019 compared to the same period of 2018 primarily due to the increase in lower margin projects and operating
expenses in 2019.
U.S. Federal
Revenues. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Income before taxes . . . . . . . . . . . . . . . . . . . . . . . . . . $
287,426
40,553
$
$
246,309
36,332
$
$
41,117
4,221
16.7%
11.6%
Year Ended December 31,
2018
2019
Dollar
Change
Percentage
Change
Revenues for the U.S. Federal segment increased by $41.1 million, or 16.7%, to $287.4 million for the twelve months
ended December 31, 2019 compared to the same period of 2018, primarily due to timing of revenue recognized as a result of
the phase of active projects.
Income before taxes for the U.S. Federal segment increased by $4.2 million, or 11.6%, to $40.6 million for the twelve
months ended December 31, 2019 compared to the same period of 2018, primarily due to an increase in revenues described
above and decrease in operating expenses attributed to lower project development costs.
Canada
Revenues. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Income (loss) before taxes . . . . . . . . . . . . . . . . . . . . . $
37,910
1,771
$
$
$
38,982
(2,746) $
(1,072)
4,517
(2.7)%
164.5 %
Year Ended December 31,
2018
2019
Dollar
Change
Percentage
Change
38 Revenues for the Canada segment decreased $1.1 million, or 2.7%, to $37.9 million for the twelve months ended
December 31, 2019 compared to the same period of 2018 primarily due to a decrease in project revenues related to slower
progression of certain active projects.
Income (loss) before taxes for the Canada segment increased $4.5 million, or 164.5%, to an income of $1.8 million for the
twelve months ended December 31, 2019 compared to a loss of $2.7 million for the same period of 2018 primarily due to a
decrease in operating expenses attributed to lower salaries and benefits and project development costs, lower interest expenses
and favorable foreign currency exchange rate fluctuations.
Non-Solar DG
Revenues. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Income before taxes . . . . . . . . . . . . . . . . . . . . . . . . . . $
84,683
3,813
$
$
82,655
13,412
$
$
2,028
(9,599)
2.5 %
(71.6)%
Year Ended December 31,
2018
2019
Dollar
Change
Percentage
Change
Revenues for the Non-Solar DG segment increased $2.0 million, or 2.5%, to $84.7 million for the twelve months ended
December 31, 2019 compared to the same period of 2018 primarily due to an increase in project and operations and
maintenance revenue partially offset by a decrease in energy and incentive revenue.
Income before taxes for the Non-Solar DG segment decreased by $9.6 million, or 71.6%, to $3.8 million for the twelve
months ended December 31, 2019 compared to the same period of 2018 primarily due to the increase in lower margin project
revenues and lower margin energy and incentive revenue attributed to lower pricing realized from the sale of certain
environmental attributes.
All Other
Year Ended December 31,
2018
2019
Dollar
Change
Percentage
Change
Revenues. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Income before taxes . . . . . . . . . . . . . . . . . . . . . . . . . . $
Unallocated corporate activity . . . . . . . . . . . . . . . . . . $
91,854
$
8,647
$
(34,156) $
84,848
$
5,264
$
(30,415) $
7,006
3,383
(3,741)
8.3 %
64.3 %
(12.3)%
Revenues from all other segments increased $7.0 million, or 8.3%, to $91.9 million for the twelve months ended December
31, 2019 compared to the same period of 2018 primarily due to an increase in integrated-PV revenues attributed to sales to
customers for oilfield microgrid applications.
Income before taxes from all other segments increased $3.4 million to income of $8.6 million for the twelve months ended
December 31, 2019 compared to the same period of 2018 primarily due to the increase in revenues described above.
Unallocated corporate activity includes all corporate level selling, general and administrative expenses and other expenses
not allocated to the segments. We do not allocate any indirect expenses to the segments.
Corporate activity increased by $3.7 million, or 12.3%, to $34.2 million for the twelve months ended December 31, 2019
compared to the same period of 2018 primarily due to an increase in salary and benefit costs and insurance costs.
39 Liquidity and Capital Resources
Sources of liquidity. Since inception, we have funded operations primarily through cash flow from operations, advances
from Federal ESPC projects and various forms of debt.
The changes in cash and cash equivalents for the years ended December 31, 2019 and 2018 were as follows:
Cash flows used in operating activities . . . . . . . . . . . . . . . . . . . . . . . . . . $
Cash flows used in investing activities. . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash flows provided by financing activities. . . . . . . . . . . . . . . . . . . . . . .
Effect of exchange rate changes on cash . . . . . . . . . . . . . . . . . . . . . . . . .
Net increase (decrease) in cash and cash equivalents. . . . . . . . . . . . . . . . $
Year Ended December 31,
2019
2018
(196,293) $
(142,223)
317,419
447
(20,650) $
(53,201)
(133,206)
224,511
(295)
37,809
We believe that cash and cash equivalents, and availability under our revolving senior secured credit facility, combined
with our access to credit markets, will be sufficient to fund our operations through at least March 2021 and thereafter.
Proceeds from our Federal ESPC projects are generally received through agreements to sell the ESPC receivables related to
certain ESPC contracts to third-party investors. We use the advances from the investors under these agreements to finance the
projects. We are the primary obligor for financing received, but only until final acceptance of the work by the customer. At this
point recourse to us ceases and the ESPC receivables are transferred to the investor. The transfers of receivables under these
agreements do not qualify for sales accounting until final customer acceptance of the work, so the advances from the investors
are not classified as operating cash flows. Cash draws that we receive under these ESPC agreements were $199.4 million during
the year ended December 31, 2019, and are recorded as financing cash inflows. The use of the cash received under these
arrangements is to pay project costs classified as operating cash flows, totaled $(188.1) million during the year ending
December 31, 2019. Due to the manner in which the ESPC contracts with the third-party investors are structured, our reported
operating cash flows are materially impacted by the fact that operating cash flows only reflect the ESPC contract expenditure
outflows and do not reflect any inflows from the corresponding contract revenues. Upon acceptance of the project by the
federal customer the ESPC receivable and corresponding ESPC liability are removed from our consolidated balance sheets as a
non-cash settlement. See Note 2, “Summary of Significant Accounting Policies”, to our Consolidated Financial Statements
appearing in Item 8 of this Annual Report on Form 10-K.
Our service offering also includes the development, construction and operation of small-scale renewable energy plants.
Small-scale renewable energy projects, or energy assets, can either be developed for the portfolio of assets that we own and
operate or designed and built for customers. Expenditures related to projects that we own are recorded as cash outflows from
investing activities. Expenditures related to projects that we build for customers are recorded as cash outflows from operating
activities as cost of revenues.
Capital expenditures. Our total capital expenditures were $140.6 million and $129.6 million for the the year ended
December 31, 2019 and 2018, respectively. Additionally, we invested $1.3 million in acquisitions for the twelve months ended
December 31, 2019, and we invested $3.6 million in acquisitions for the year ended December 31, 2018. Included in our capital
expenditures are the purchases of solar PV projects in development for $8.5 million and $72.9 million for the years ended
December 31, 2019 and 2018, respectively . We currently plan to invest approximately $200.0 million to $250.0 million in
capital expenditures in 2020, principally for the construction or acquisition of new renewable energy plants.
Cash flows from operating activities. Operating activities used $196.3 million of net cash during 2019. In 2019, we had net
income of $40.3 million, which is net of non-cash compensation, depreciation, amortization, deferred income taxes and other
non-cash items totaling $36.5 million. Net increases in costs and estimated earnings in excess of billings, accounts receivable
including retainage, inventory, prepaid expenses and other current assets and net decreases in other liabilities and income taxes
payable used $140.4 million. These uses of cash were offset by net decreases in project development costs and other assets and
an increase in accounts payable and accrued expenses, and billings in excess of cost and estimated earnings which provided
$55.4 million. Federal ESPC receivables used $188.1 million. As described above, Federal ESPC operating cash flows only
reflect the ESPC expenditure outflows and do not reflect any inflows from the corresponding contract revenues, which are
recorded as cash inflows from financing activities due to the timing of the receipt of cash related to the assignment of the ESPC
receivables to the third-party investors.
40 Operating activities used $53.2 million of net cash during 2018. In 2018, we had a net income of $37.6 million, which is
net of non-cash compensation, depreciation, amortization, deferred income taxes and other non-cash items totaling $42.1
million. Net increases in project development costs and other assets and net decreases in other liabilities used $12.9 million.
These uses of cash were offset by net decrease in accounts receivable including retainage, inventory, costs and estimated
earnings in excess of billings, prepaid expenses and other current assets and an increase in accounts payable, accrued expenses
and other current liabilities, billings in excess of cost and estimated earnings and income taxes payable which provided $35.6
million. Federal ESPC receivables used $155.5 million.
Cash flows from investing activities. Cash used for investing activities totaled $142.2 million during 2019 and consisted of
capital investments, net of grant proceeds, of $134.0 million related to the development and acquisition of renewable energy
plants, $6.7 million related to purchases of other property and equipment, acquisitions of businesses of $1.3 million and
contributions to equity investments of $0.3 million.
Cash used for investing activities totaled $133.2 million during 2018 and consisted of capital investments of $125.7 million
related to the development and acquisition of renewable energy plants, $3.9 million related to purchases of other property and
equipment and $3.6 million related to acquisitions of renewable energy businesses.
Cash flows from financing activities. Net cash provided by financing activities totaled $317.4 million during 2019 and
included repayments of $28.4 million on long-term debt, payments of $1.7 million relating to financing fees and $0.1 million
for the repurchase of stock. These uses of financing cash were offset by proceeds from our senior secured credit facility of
$73.3 million and long-term debt financings of $43.9 million, contributions from redeemable non-controlling interests of $21.4
million and proceeds from exercises of options which provided $7.4 million. Proceeds from Federal ESPC projects and energy
assets provided $201.6 million in cash.
Net cash provided by financing activities totaled $224.5 million during 2018 and included repayments of $36.4 million on
long-term debt, payments of $4.1 million relating to financing fees, $1.8 million for the repurchase of stock and net payments
on our senior secured credit facility of $0.9 million. These uses of financing cash were offset by proceeds from long-term debt
financings of $88.1 million, proceeds from sale-leaseback financings of $5.1 million, contributions from redeemable non-
controlling interests of $4.8 million and proceeds from exercises of options which provided $7.2 million. Proceeds from Federal
ESPC projects and energy assets provided $162.5 million in cash.
We currently plan additional financings of $125.0 million to $175.0 million in 2020 to fund the construction or acquisition
of new renewable energy plants as discussed above.
We may also, from time to time, finance our operations through issuance or offering of equity or debt securities.
Senior Secured Credit Facility — Revolver and Term Loan
On June 28, 2019, we entered into a fourth amended and restated bank credit facility with three banks. The new credit
facility replaces and extends our existing credit facility, which was scheduled to expire on June 30, 2020. The amended
revolving credit and term loan facility mature on June 28, 2024, when all amounts will be due and payable in full. The
Company expects to use the new credit facility for general corporate purposes of the Company and its subsidiaries, including
permitted acquisitions, refinancing of existing indebtedness and working capital. The amendment increased the aggregate
amount of the revolving commitments from $85,000 to $115,000 through an extended June 28, 2024 maturity date, increased
the term loan from $40,000 to $65,000 to reduce the outstanding revolving loan balance by the same amount and extend the
maturity date from June 30, 2020 to June 28, 2024, and increased the total funded debt to EBITDA covenant ratio from a
maximum of 3.00 to 3.25. The total commitment under the amended credit facility (revolving credit, term loan and swing line)
is $185,000.
The credit facility consists of a $115 million revolving credit facility and a $65 million term loan. The revolving credit
facility may be increased by up to an additional $25 million at our option if lenders are willing to provide such increased
commitments, subject to certain conditions. Up to $20 million of the revolving credit facility may be borrowed in Canadian
dollars, Euros and Pounds Sterling. We are the sole borrower under the credit facility. The obligations under the credit facility
are guaranteed by certain of our direct and indirect wholly owned domestic subsidiaries and are secured by a pledge of all of
our and such of our subsidiary guarantors’ assets, other than the equity interests of certain subsidiaries and assets held in non-
core subsidiaries (as defined in the agreement). At December 31, 2019 and 2018, $62.6 million and $41.5 million, was
outstanding under the term loan, respectively. At December 31, 2019 and 2018, $50.0 million and $1.7 million was outstanding
under the revolving credit facility, respectively. At December 31, 2019 funds of $29.1 million was available for the revolving
credit facility.
41 The interest rate for borrowings under the credit facility is based on, at our option, either (1) a base rate equal to a margin
of 0.5% or 0.25%, depending on our ratio of Total Funded Debt to EBITDA (each as defined in the agreement), over the highest
of (a) the federal funds effective rate, plus 0.50% , (b) Bank of America’s prime rate and (c) a rate based on the London
interbank deposit rate (“LIBOR”) plus 1.50%, or (2) the one-, two- three- or six-month LIBOR plus a margin of 2.00% or
1.75%, depending on our ratio of Total Funded Debt to EBITDA. A commitment fee of 0.375% is payable quarterly on the
undrawn portion of the revolving credit facility. At December 31, 2019, the interest rate for borrowings under the revolving
credit facility was 4.52% and the weighted average interest rate for borrowings under the term loan was 4.27%.
The revolving credit facility does not require amortization of principal. The term loan requires quarterly principal payments
of $1.2 million, with the balance due at maturity. All borrowings may be paid before maturity in whole or in part at our option
without penalty or premium, other than reimbursement of any breakage and deployment costs in the case of LIBOR
borrowings.
The credit facility limits our ability to, among other things: incur additional indebtedness; incur liens or guarantee
obligations; merge, liquidate or dispose of assets; make acquisitions or other investments; enter into hedging agreements; pay
dividends and make other distributions and engage in transactions with affiliates, except in the ordinary course of business on
an arms’ length basis.
Under the credit facility, we may not invest cash or property in, or loan to, our non-core subsidiaries in aggregate amounts
exceeding 49% of our consolidated stockholders’ equity. In addition, under the credit facility, we and our core subsidiaries must
maintain the following financial covenants:
a ratio of total funded debt to EBITDA of less than 3.25 to 1.0 as of the end of each fiscal quarter ending June 30,
2024 and thereafter; and
a debt service coverage ratio (as defined in the agreement) of at least 1.5 to 1.0.
•
•
Any failure to comply with the financial or other covenants of the credit facility would not only prevent us from being able
to borrow additional funds, but would constitute a default, permitting the lenders to, among other things, accelerate the amounts
outstanding, including all accrued interest and unpaid fees, under the credit facility, to terminate the credit facility, and enforce
liens against the collateral.
The credit facility also includes several other customary events of default, including a change in control, permitting the
lenders to accelerate the indebtedness, terminate the credit facility, and enforce liens against the collateral.
Project Financing
Construction and Term Loans. We have entered into a number of construction and term loan agreements for the purpose of
constructing and owning certain renewable energy plants. The physical assets and the operating agreements related to the
renewable energy plants are generally owned by wholly owned, single member “special purpose” subsidiaries of the Company.
These construction and term loans are structured as project financings made directly to a subsidiary, and upon commercial
operations and achieving certain milestones in the credit agreement, the related construction loan converts into a term loan.
While we are required under GAAP to reflect these loans as liabilities on our consolidated balance sheets, they are generally
non-recourse and not direct obligations of Ameresco, Inc. As of December 31, 2019, we had outstanding $204.5 million in
aggregate principal amount under these loans with maturities at various dates from 2020 to 2039. Effective interest rates, after
consideration for our interest rate swap contracts, ranged from 0% to 9.41%. As of December 31, 2018, we had outstanding
$179.9 million in aggregate principal amount under these loans with maturities at various dates from 2020 to 2038. Effective
interest rates, after consideration for our interest rate swap contracts, ranged from 4.38% to 9.89% as of December 31, 2018.
The Company’s project financing facilities contain various financial and other covenant requirements which include debt
service coverage ratios and total funded debt to EBITDA, as defined. Any failure to comply with the financial or other
covenants of the Company’s projects financings would result in inability to distribute funds from the wholly-owned subsidiary
to the Company or constitute an event of default in which the lenders may have the ability to accelerate the amounts
outstanding, including all accrued interest and unpaid fees.
42 As of December 31, 2019 and 2018, the Company’s debt, excluding financing leases, consisted of the following:
Commencement
Date
Maturity Date
Balance as of December
31,
2019
2018
Senior secured credit facility, interest at
varying rates monthly in arrears. . . . . . . June 2015
Variable rate term loan payable in semi-
annual installments. . . . . . . . . . . . . . . . . January 2006
Variable rate term loan payable in semi-
annual installments. . . . . . . . . . . . . . . . . January 2006
Term loan payable in quarterly
installments. . . . . . . . . . . . . . . . . . . . . . . March 2011
Term loan payable in monthly
installments. . . . . . . . . . . . . . . . . . . . . . . October 2011
Variable rate term loan payable in
quarterly installments . . . . . . . . . . . . . . . October 2012
June 2024
$112,216
$ 43,074
February 2021
625
936
June 2024
6,609
7,426
March 2021
831
1,464
June 2028
3,649
3,843
June 2020
28,217
30,674
June 2031
April 2027
March 2028
February 2034
Variable rate term loan payable in
quarterly installments . . . . . . . . . . . . . . . September 2015 March 2023
Term loan payable in quarterly
installments. . . . . . . . . . . . . . . . . . . . . . . August 2016
Term loan payable in quarterly
installments. . . . . . . . . . . . . . . . . . . . . . . March 2017
Term loan payable in monthly
installments. . . . . . . . . . . . . . . . . . . . . . . April 2017
Term loan payable in quarterly
installments. . . . . . . . . . . . . . . . . . . . . . . April 2017
Variable rate term loan payable in
quarterly installments . . . . . . . . . . . . . . . June 2017
Variable rate term loan payable in
quarterly installments . . . . . . . . . . . . . . . February 2018 August 2022
Term loan payable in quarterly
installments. . . . . . . . . . . . . . . . . . . . . . . June 2018
Variable rate term loan payable in semi-
annual installments. . . . . . . . . . . . . . . . . June 2018
Variable rate term loan payable in
monthly/quarterly installments. . . . . . . . October 2018
Long term finance liability in semi-
annual installments. . . . . . . . . . . . . . . . . July 2019
Long term finance liability in semi-
annual installments. . . . . . . . . . . . . . . . . November 2019 November 2039
Term loan payable in quarterly
installments. . . . . . . . . . . . . . . . . . . . . . . December 2019 December 2021
Total construction and term loans . . . . .
December 2038
December 2027
October 2029
June 2033
July 2039
15,976
17,208
3,769
3,925
3,521
3,945
22,553
22,081
2,706
2,735
11,740
12,915
15,645
21,475
28,583
30,069
9,003
9,668
9,092
9,072
3,841
8,794
—
—
27,226
$314,596
—
$ 220,510
Federal ESPC liabilities. We have arrangements with certain third-parties to provide advances to us during the construction
or installation of projects for certain customers, typically federal governmental entities, in exchange for our assignment to the
lenders of our rights to the long-term receivables arising from the ESPCs related to such projects. These financings totaled
$245.0 million and $288.0 million in principal amounts at December 31, 2019 and 2018, respectively. Under the terms of these
financing arrangements, we are required to complete the construction or installation of the project in accordance with the
contract with our customer, and the liability remains on our consolidated balance sheets until the completed project is accepted
by the customer.
43 Sale-Leaseback/Finance Liabilities. During the first quarter of 2015, we entered into an agreement with an investor which
gives us the option to sell and contemporaneously lease back solar photovoltaic (“solar PV”) projects. This agreement expired
on June 30, 2018. During the year ended December 31, 2017, we sold twelve solar PV projects and in return received $47.2
million as part of this arrangement. Additionally, we sold and contemporaneously leased back one solar PV project to a separate
investor, not a party to the master lease agreement, under a new agreement during the year ended December 31, 2017, and in
return received $2.0 million. In August 2018, we entered into an agreement with an investor which gives us the option to sell
and contemporaneously lease back solar PV projects through August 2019 up to a maximum funding amount of $100 million.
During the year ended December 31, 2018, we sold two solar PV projects and in return received $4.9 million as part of this
arrangement.
During the year ended December 31, 2019, we amended the August 2018 agreement with the investor to extend the end
date of the agreement to November 24, 2019, and we sold three projects and in return received $13.7 million. In accordance
with Topic 842, Leases, these transactions were accounted for as failed sales as we retain control of the underlying assets. We
recorded the proceeds received from the transactions as long term financing facilities with interest rates ranging from 0% to
0.28%, as a result of tax credits which were transferred to the counterparties. As of December 31, 2019, approximately $81
million remained available under the lending commitment although this full amount is not expected to be used.
In January 2020, we amended the August 2018 agreement with the investor to extend the end date of the agreement to
November 24, 2020 and increase the maximum funding amount up to $150 million. While we are required under GAAP to
reflect these lease payments as liabilities on our consolidated balance sheets, they are generally non-recourse and not direct
obligations of Ameresco, Inc., except that Ameresco, Inc. has guaranteed certain obligations relating to taxes and project
warranties, operation and maintenance.
Contractual Obligations
The following table summarizes our significant contractual obligations and commitments as of December 31, 2019 (in
thousands):
Less than
One Year
Payments due by Period
One to
Three Years
Three to
Five Years
More than
Five Years
Total
Senior Secured Credit Facility:
Revolver . . . . . . . . . . . . . . . . . . . . . . . . . .
Term Loan . . . . . . . . . . . . . . . . . . . . . . . . .
$
50,073
$
— $
— $
50,073
$
62,563
4,875
14,625
43,063
Project Financing:
Construction and term loans . . . . . . . . . . .
Federal ESPC liabilities(1) . . . . . . . . . . . .
Interest obligations(2). . . . . . . . . . . . . . . . . . . .
Financing lease liabilities . . . . . . . . . . . . . . . . .
Operating leases . . . . . . . . . . . . . . . . . . . . . . . .
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
204,470
245,037
81,691
28,497
55,234
60,097
—
17,449
4,997
9,153
75,534
245,037
26,753
9,431
14,115
22,331
—
16,432
1,802
9,375
$
727,565
$
96,571
$
385,495
$
143,076
$
102,423
—
—
46,508
—
21,057
12,267
22,591
(1)
Federal ESPC arrangements relate to the installation and construction of projects for certain customers, typically
federal governmental entities, where we assign to third-parties our right to customer receivables. We are relieved of
the liability, without making a payment, when the project is completed and accepted by the customer. We typically
expect to be relieved of the liability between one and three years from the date of project construction
commencement. The table does not include, for our Federal ESPC liability arrangements, the difference between the
aggregate amount of the long-term customer receivables sold by us to the third-party and the amount received by us
from the third party for such sale.
(2)
For both the revolving and term loan portions of our senior secured credit facility, the table above assumes that the
variable interest rate in effect at December 31, 2019 remains constant for the term of the facility.
44 Off-Balance Sheet Arrangements
We did not have during the periods presented, and we do not currently have, any off-balance sheet arrangements, as defined
under SEC rules, such as relationships with unconsolidated entities or financial partnerships, which are often referred to as
structured finance or special purpose entities, established for the purpose of facilitating financing transactions that are not
required to be reflected on our balance sheets. The Company from time to time issues letters of credit and performance bonds,
with their third-party lenders, to provide collateral.
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
We are exposed to changes in interest rates and foreign currency exchange rates because we finance certain operations
through fixed and variable rate debt instruments and denominate our transactions in U.S. and Canadian dollars and British
pounds sterling (“GBP”). Changes in these rates may have an impact on future cash flows and earnings. We manage these risks
through normal operating and financing activities and, when deemed appropriate, through the use of derivative financial
instruments.
Interest Rate Risk
We had cash and cash equivalents totaling $33.2 million as of December 31, 2019 and $61.4 million as of December 31,
2018. Our exposure to interest rate risk primarily relates to the interest expense paid on our senior secured credit facility.
Derivative Instruments
We do not enter into financial instruments for trading or speculative purposes. However, through our subsidiaries we do
enter into derivative instruments for purposes other than trading purposes. Certain of the term loans that we use to finance our
renewable energy projects bear variable interest rates that are indexed to short-term market rates. We have entered into interest
rate swaps in connection with these term loans in order to seek to hedge our exposure to adverse changes in the applicable
short-term market rate. In some instances, the conditions of our renewable energy project term loans require us to enter into
interest rate swap agreements in order to mitigate our exposure to adverse movements in market interest rates. All but one of the
interest rate swaps that we have entered into qualify and have been designated as fair value hedges. We have also entered into
two commodity swap contracts in order to hedge our exposure to adverse changes in the short-term market rates of natural gas,
which have not been designated for hedge accounting. See Notes 2, 18 and 19 of “Notes to Consolidated Financial Statements”
included in Item 8 of this Annual Report on Form 10-K.
We have also entered into term loan agreements that contain interest make-whole provisions that qualify as embedded
derivatives that are required to be bifurcated from their host term loan agreement and valued separately. These derivatives
cannot be hedged. See Notes 2, 18 and 19 of “Notes to Consolidated Financial Statements” included in Item 8 of this Annual
Report on Form 10-K.
By using derivative instruments, we are subject to credit and market risk. The fair market value of the interest rate and
commodity swaps are determined by using valuation models whose inputs are derived using market observable inputs,
including interest rate yield curves, and reflects the asset or liability position as of the end of each reporting period. When the
fair value of a derivative contract is positive, the counterparty owes us, thus creating a receivable risk for us. We are exposed to
counterparty credit risk in the event of non-performance by counterparties to our derivative agreements. We minimize
counterparty credit (or repayment) risk by entering into transactions with major financial institutions of investment grade credit
rating. The fair value of these make-whole provisions was determined based on available market data and a with and without
model.
Our exposure to market interest rate risk is not hedged in a manner that completely eliminates the effects of changing
market conditions on earnings or cash flow.
Foreign Currency Risk
We have revenues, expenses, assets and liabilities that are denominated in foreign currencies, principally the Canadian
dollar and British pound sterling. Also, a significant number of employees are located in Canada and the U.K., and our
subsidiaries in those countries transact business in those respective currencies. As a result, we have designated the Canadian
dollar as the functional currency for Canadian operations. Similarly, the GBP has been designated as the functional currency for
our operations in the U.K. When we consolidate the operations of these foreign subsidiaries into our financial results, because
45 we report our results in U.S. dollars, we are required to translate the financial results and position of our foreign subsidiaries
from their respective functional currencies into U.S. dollars. We translate the revenues, expenses, gains, and losses from our
Canadian and U.K. subsidiaries into U.S. dollars using a weighted average exchange rate for the applicable fiscal period. We
translate the assets and liabilities of our Canadian and U.K. subsidiaries into U.S. dollars at the exchange rate in effect at the
applicable balance sheet date. Translation adjustments are not included in determining net income for the period but are
disclosed and accumulated in a separate component of consolidated equity until sale or until a complete or substantially
complete liquidation of the net investment in our foreign subsidiary takes place. Changes in the values of these items from one
period to the next which result from exchange rate fluctuations are recorded in our consolidated statements of changes in
stockholders’ equity as accumulated other comprehensive loss. For the year ended December 31, 2019, due to the strengthening
of the GBP and CAD versus the U.S. dollar, our foreign currency translation resulted in a gain of $1.4 million which we
recorded as a decrease in accumulated other comprehensive loss. For the year ended December 31, 2018, the weakening of the
GBP versus the U.S. dollar, our foreign currency translation resulted in a loss of $0.3 million, which we recorded as an increase
in accumulated other comprehensive loss. As a consequence, gross profit, operating results, profitability and cash flows are
impacted by relative changes in the value of the Canadian dollar and GBP. We have not repatriated earnings from our foreign
subsidiaries, but have elected to invest in new business opportunities there. See Note 10, “Income Taxes” to our consolidated
financial statements appearing in Item 8 of this Annual Report on Form 10-K. We do not hedge our exposure to foreign
currency exchange risk.
46 Item 8. Financial Statements and Supplementary Data
AMERESCO, INC.
CONSOLIDATED BALANCE SHEETS
(in thousands, except share amounts)
December 31,
2019
2018
ASSETS
Current assets:
Cash and cash equivalents (including amounts in VIEs of $4,666 and $1,255, respectively) . . . . . . . . . $
33,223
$
Restricted cash (including amounts in VIEs of $586 and $156, respectively). . . . . . . . . . . . . . . . . . . . .
Accounts receivable, net (including amounts in VIEs of $532 and $374, respectively) . . . . . . . . . . . . .
Accounts receivable retainage, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Costs and estimated earnings in excess of billings (including amounts in VIEs of $1,125 and $498,
respectively) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Inventory, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Prepaid expenses and other current assets (including amounts in VIEs of $108 and $190,
respectively) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Income tax receivable. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Project development costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total current assets. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Federal ESPC receivable. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Property and equipment, net (including amounts in VIEs of $1,266 and $0, respectively) . . . . . . . . . . . .
Energy assets, net (including amounts in VIEs of $142,456 and $122,641, respectively) . . . . . . . . . . . . .
Goodwill . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Intangible assets, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Operating lease assets (including amounts in VIEs of $6,511 and $0, respectively) . . . . . . . . . . . . . . . . .
Other assets (including amounts in VIEs of $1,662 and $1,613, respectively) . . . . . . . . . . . . . . . . . . . . .
20,006
95,863
16,976
202,243
9,236
29,424
5,033
13,188
425,192
230,616
10,104
579,461
58,414
1,614
32,791
35,821
61,397
16,880
85,985
13,516
86,842
7,765
11,571
5,296
21,717
310,969
293,998
6,985
459,952
58,332
2,004
—
29,394
Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
1,374,013
$
1,161,634
LIABILITIES, REDEEMABLE NON-CONTROLLING INTERESTS AND STOCKHOLDERS’ EQUITY
Current liabilities:
Current portions of long-term debt and financing lease liabilities (including amounts in VIEs of
$2,252 and $1,712, respectively) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
69,969
$
Accounts payable (including amounts in VIEs of $2,006 and $234, respectively) . . . . . . . . . . . . . . . . .
202,416
26,890
134,330
Accrued expenses and other current liabilities (including amounts in VIEs of $2,203 and $4,146,
respectively) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
31,356
35,947
Current portions of operating lease liabilities (including amounts in VIEs of $102 and $0,
respectively) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Billings in excess of cost and estimated earnings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Income taxes payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term debt and financing lease liabilities, less current portions and net of deferred financing fees
(including amounts in VIEs of $24,654 and $26,461, respectively). . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Federal ESPC liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred income taxes, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred grant income. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term portions of operating lease liabilities, less current portions (including amounts in VIEs of
$6,180 and $0, respectively) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other liabilities (including amounts in VIEs of $1,171 and $2,131, respectively). . . . . . . . . . . . . . . . . . .
Commitments and contingencies (Note 15)
5,802
26,618
486
336,647
266,181
245,037
115
6,885
29,101
29,575
—
24,363
1,100
222,630
219,162
288,047
4,352
6,637
—
29,212
Redeemable non-controlling interests. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
31,616
14,719
The accompanying notes are an integral part of these consolidated financial statements.
47 AMERESCO, INC.
CONSOLIDATED BALANCE SHEETS — (Continued)
(in thousands, except share amounts)
Stockholders’ equity:
Preferred stock, $0.0001 par value, 5,000,000 shares authorized, no shares issued and
outstanding at December 31, 2019 and 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Class A common stock, $0.0001 par value, 500,000,000 shares authorized, 31,331,345
shares issued and 29,230,005 shares outstanding at December 31, 2019, 30,366,546
shares issued and 28,275,506 shares outstanding at December 31, 2018 . . . . . . . . . . . . . .
Class B common stock, $0.0001 par value, 144,000,000 shares authorized, 18,000,000
shares issued and outstanding at December 31, 2019 and 2018 . . . . . . . . . . . . . . . . . . . . .
Additional paid-in capital. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Retained earnings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accumulated other comprehensive loss, net of income taxes . . . . . . . . . . . . . . . . . . . . . . .
Less - treasury stock, at cost, 2,101,340 shares at December 31, 2019, and 2,091,040
shares at December 31, 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total stockholder’s equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total liabilities, redeemable non-controlling interests and stockholders’ equity. . . . . $
December 31,
2019
2018
— $
3
2
133,688
314,459
(7,514)
—
3
2
124,651
269,806
(5,949)
(11,782)
428,856
1,374,013
$
(11,638)
376,875
1,161,634
The accompanying notes are an integral part of these consolidated financial statements.
48 AMERESCO, INC.
CONSOLIDATED STATEMENTS OF INCOME
(in thousands, except per share amounts)
2019
Year Ended December 31,
2018
2017
Revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Cost of revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Gross profit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Selling, general and administrative expenses. . . . . . . . . . . . . . . . . . . . . .
Operating income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other expenses, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Income before (benefit) provision for income taxes. . . . . . . . . . . . . . .
Income tax (benefit) provision . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net loss attributable to redeemable non-controlling interests . . . . . . . . .
Net income attributable to common shareholders . . . . . . . . . . . . . . . . . . $
Net income per share attributable to common shareholders:
Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Weighted average common shares outstanding:
Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
$
$
$
866,933
698,815
168,118
116,504
51,614
15,061
36,553
(3,748)
40,301
4,135
44,436
0.95
0.93
46,586
47,774
$
$
$
$
787,138
613,526
173,612
114,513
59,099
16,709
42,390
4,813
37,577
407
37,984
0.83
0.81
45,729
46,831
717,152
572,994
144,158
107,570
36,588
7,871
28,717
(4,791)
33,508
3,983
37,491
0.82
0.82
45,509
45,748
The accompanying notes are an integral part of these consolidated financial statements.
AMERESCO, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(in thousands)
Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Other comprehensive income (loss):
Unrealized (loss) gain from interest rate hedges, net of tax effect of
$(984), $(12) and $(35), respectively . . . . . . . . . . . . . . . . . . . . . . . . .
Foreign currency translation adjustment . . . . . . . . . . . . . . . . . . . . . . .
Total other comprehensive income (loss). . . . . . . . . . . . . . . . . . . . . . . . .
Comprehensive income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Comprehensive loss attributable to redeemable non-controlling
interests. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Comprehensive income attributable to common shareholders . . . . . . . . $
Year Ended December 31,
2019
2018
2017
40,301
$
37,577
$
33,508
(2,944)
1,379
(1,565)
38,736
(73)
(250)
(323)
37,254
4,135
42,871
$
407
37,661
$
310
655
965
34,473
3,983
38,456
The accompanying notes are an integral part of these consolidated financial statements.
49 .
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50
AMERESCO, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands)
Cash flows from operating activities:
Net income. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
40,301
37,577
$
33,508
2019
Year Ended December 31,
2018
2017
Adjustments to reconcile net income to net cash flows from operating
activities:
Depreciation of energy assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Depreciation of property and equipment. . . . . . . . . . . . . . . . . . . . . . . .
Amortization of deferred financing fees . . . . . . . . . . . . . . . . . . . . . . . .
Amortization of intangible assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accretion of ARO and contingent consideration. . . . . . . . . . . . . . . . . .
Provision for (recovery of) bad debts . . . . . . . . . . . . . . . . . . . . . . . . . .
Loss (gain) on disposal / sale of assets . . . . . . . . . . . . . . . . . . . . . . . . .
Net gain from derivatives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Stock-based compensation expense . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred income taxes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Unrealized foreign exchange loss (gain) . . . . . . . . . . . . . . . . . . . . . . . .
Changes in operating assets and liabilities: . . . . . . . . . . . . . . . . . . . . . . .
Accounts receivable. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accounts receivable retainage. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Federal ESPC receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Inventory, net. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Costs and estimated earnings in excess of billings . . . . . . . . . . . . . . . .
Prepaid expenses and other current assets. . . . . . . . . . . . . . . . . . . . . . .
Project development costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accounts payable, accrued expenses and other current liabilities . . . .
Billings in excess of cost and estimated earnings . . . . . . . . . . . . . . . . .
Other liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Income taxes payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash flows from operating activities . . . . . . . . . . . . . . . . . . . . . . . .
Cash flows from investing activities:
35,543
2,987
2,229
909
137
(216)
(2,160)
(1,068)
1,620
(3,346)
(130)
(8,499)
(3,370)
(188,060)
(1,471)
(106,696)
(18,397)
8,120
1,056
43,531
2,662
(1,625)
(350)
(196,293)
27,305
2,167
2,193
1,057
—
610
298
(121)
1,258
5,517
1,816
9,772
3,774
(155,539)
373
8,015
6,763
(8,659)
(3,499)
2,938
2,866
(783)
1,101
(53,201)
Purchases of property and equipment . . . . . . . . . . . . . . . . . . . . . . . . . .
Purchases of energy assets, net of grant proceeds . . . . . . . . . . . . . . . . .
Proceeds from sale of assets of a business . . . . . . . . . . . . . . . . . . . . . .
Acquisitions, net of cash received . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Contributions to equity investment . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash flows from investing activities. . . . . . . . . . . . . . . . . . . . . . . . . $
(6,674)
(133,954)
—
(1,294)
(301)
(142,223) $
(3,943)
(125,673)
—
(3,590)
—
(133,206) $
The accompanying notes are an integral part of these consolidated financial statements.
21,648
2,394
1,620
1,451
—
77
(103)
(271)
1,293
(4,527)
(1,406)
1,870
1,279
(157,538)
3,966
(46,730)
(2,471)
(3,007)
111
19,652
(2,168)
(540)
(5,678)
(135,570)
(2,851)
(85,559)
2,777
(2,409)
—
(88,042)
51 AMERESCO, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS — (Continued)
(in thousands)
Cash flows from financing activities:
Payments of financing fees . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Proceeds from exercises of options and ESPP . . . . . . . . . . . . . . . . . . .
Repurchase of common stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Proceeds (payments) from senior secured credit facility, net . . . . . . . .
Proceeds from long-term debt financings . . . . . . . . . . . . . . . . . . . . . . .
Proceeds from Federal ESPC projects. . . . . . . . . . . . . . . . . . . . . . . . . .
Proceeds for energy assets from Federal ESPC. . . . . . . . . . . . . . . . . . .
Proceeds from sale-leaseback financings . . . . . . . . . . . . . . . . . . . . . . .
Contributions from redeemable non-controlling interests, net . . . . . . .
Payments on long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash flows from financing activities . . . . . . . . . . . . . . . . . . . . . . . .
Effect of exchange rate changes on cash . . . . . . . . . . . . . . . . . . . . . . . . .
Net (decrease) increase in cash and cash equivalents, and restricted
cash . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash, cash equivalents, and restricted cash, beginning of year . . . . . . . .
Cash, cash equivalents, and restricted cash, end of year . . . . . . . . . . . . . $
Supplemental disclosures of cash flow information:
Cash paid for interest. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Cash paid for income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Non-cash Federal ESPC settlement. . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Accrued purchases of energy assets . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Conversion of revolver to term loan . . . . . . . . . . . . . . . . . . . . . . . . . . . $
2019
Year Ended December 31,
2018
2017
(1,666)
7,417
(144)
73,347
43,883
199,358
2,277
—
21,372
(28,425)
317,419
447
(20,650)
97,914
77,264
17,467
3,897
242,519
34,871
25,000
$
$
$
$
$
$
(4,073)
7,197
(1,839)
(900)
88,115
158,237
4,236
5,145
4,788
(36,395)
224,511
(295)
37,809
60,105
97,914
15,563
2,257
101,557
15,005
25,000
$
$
$
$
$
$
(2,877)
1,977
(3,412)
12,547
48,483
165,013
3,993
51,204
7,473
(54,164)
230,237
654
7,279
52,826
60,105
11,675
5,782
66,921
7,335
—
The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the consolidated
balance sheets to the total of the same such amounts shown above:
Cash and cash equivalents. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Short-term restricted cash . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term restricted cash included in other assets . . . . . . . . . . . . . .
Total cash and cash equivalents, and restricted cash. . . . . . . . . . . . .
$
$
33,223
20,006
24,035
77,264
$
$
61,397
16,880
19,637
97,914
$
$
24,262
15,751
20,092
60,105
Year Ended December 31,
2019
2018
2017
The accompanying notes are an integral part of these consolidated financial statements.
52 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(in thousands, except per share amounts)
1. DESCRIPTION OF BUSINESS
Ameresco, Inc. (including its subsidiaries, the “Company”) was organized as a Delaware corporation on April 25, 2000.
The Company is a provider of energy efficiency solutions for facilities throughout North America and Europe. The Company
provides solutions, both services and products, that enable customers to reduce their energy consumption, lower their operating
and maintenance costs and realize environmental benefits. The Company’s comprehensive set of solutions includes upgrades to
a facility’s energy infrastructure and the construction and operation of small-scale renewable energy plants. It also sells certain
photovoltaic (“PV”) equipment worldwide. The Company operates in the United States, Canada, United Kingdom and Europe.
The Company is compensated through a variety of methods, including: 1) direct payments based on fee-for-services
contracts (utilizing lump-sum or cost-plus pricing methodologies); 2) the sale of energy from the Company’s energy assets; and
3) direct payment for PV equipment and systems.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation
The accompanying consolidated financial statements include the accounts of the Company, its subsidiaries and certain
contracts in which the Company has a controlling financial interest and five investment funds formed to fund the purchase and
operation of solar energy systems, which are consolidated with the Company as variable interest entities (“VIE”). The
Company uses a qualitative approach in assessing the consolidation requirement for VIEs. This approach focuses on
determining whether the Company has the power to direct the activities of the VIE that most significantly affect the VIE’s
economic performance and whether the Company has the obligation to absorb losses or the right to receive benefits that could
potentially be significant to the VIE. For all periods presented, the Company has determined that it is the primary beneficiary in
all of its operational VIEs. The Company evaluates its relationships with the VIEs on an ongoing basis to ensure that it
continues to be the primary beneficiary. All significant intercompany accounts and transactions have been eliminated. Gains
and losses from the translation of all foreign currency financial statements are recorded in accumulated other comprehensive
loss, net, within stockholders’ equity. The Company prepares its consolidated financial statements in conformity with the
accounting principles generally accepted in the United States of America (“GAAP”).
Use of Estimates
GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the
disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of
revenue and expenses during the reporting period. The most significant estimates and assumptions used in these consolidated
financial statements relate to management’s estimates of final construction contract profit in accordance with accounting for
long-term contracts, allowance for doubtful accounts, inventory reserves, realization of project development costs, leases, fair
value of derivative financial instruments, accounting for business acquisitions, stock-based awards, impairment of goodwill and
long-lived assets, asset retirement obligations (“AROs”), income taxes, self insurance reserves and potential liability in
conjunction with certain commitments and contingencies. Actual results could differ from those estimates.
The Company is self-insured for employee health insurance. The maximum exposure in fiscal year 2019 under the plan
was $150 per covered participant, after which reinsurance takes effect. The liability for unpaid claims and associated expenses,
including incurred but not reported claims, is determined by management and reflected in the Company’s consolidated balance
sheets in accrued expenses and other current liabilities. The liability is calculated based on historical data, which considers both
the frequency and settlement amount of claims. The Company’s estimated accrual for this liability could be different than its
ultimate obligation if variables such as the frequency or amount of future claims differ significantly from management’s
assumptions. 5
Cash and Cash Equivalents
Cash and cash equivalents includes cash on deposit, overnight repurchase agreements and amounts invested in highly
liquid money market funds. Cash equivalents consist of short term investments with original maturities of three months or less.
The Company maintains its accounts with financial institutions and the balances in such accounts, at times, exceed federally
insured limits. This credit risk is divided among a number of financial institutions that management believes to be of high
quality. The carrying amount of cash and cash equivalents approximates its fair value measured using level 1 inputs per the fair
value hierarchy as defined in Note 18.
53 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Restricted Cash
Restricted cash consists of cash and cash equivalents held in an escrow account in association with construction draws for
energy savings performance contracts (“ESPC”), construction of energy assets, operations and maintenance (“O&M”) reserve
accounts, cash collateralized letters of credit as well as cash required under term loans to be maintained in debt service reserve
accounts until all obligations have been indefeasibly paid in full. These accounts are primarily invested in highly liquid money
market funds. The carrying amount of the cash and cash equivalents in these accounts approximates its fair value measured
using level 1 inputs per the fair value hierarchy as defined in Note 18. Restricted cash also includes funds held for clients,
which represent assets that, based upon the Company’s intent, are restricted for use solely for the purposes of satisfying the
obligations to remit funds to third parties, primarily utility service providers, relating to the Company’s enterprise energy
management services. As of December 31, 2019 and 2018, the Company classified the non-current portion of restricted cash of
$24,035 and $19,637, respectively, in other assets on its consolidated balance sheets.
Accounts Receivable
Accounts receivable are stated at the amount management expects to collect from outstanding balances. An allowance for
doubtful accounts is provided for those accounts receivable considered to be uncollectible based upon historical experience and
management’s evaluation of outstanding accounts receivable. Bad debts are written off against the allowance when identified.
Changes in the allowance for doubtful accounts are as follows:
Allowance for doubtful accounts, beginning of period . . . . . . . . . . . . . . $
Charges (recovery) to costs and expenses, net . . . . . . . . . . . . . . . . . . . . .
Account write-offs and other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Allowance for doubtful accounts, end of period . . . . . . . . . . . . . . . . . . . $
Accounts Receivable Retainage
Year Ended December 31,
2019
2018
2017
2,765
(216)
(289)
2,260
$
$
3,315
610
(1,160)
2,765
$
$
7,836
81
(4,602)
3,315
Accounts receivable retainage represents amounts due from customers, but where payments are withheld contractually
until certain construction milestones are met. Amounts retained typically range from 5% to 10% of the total invoice. The
Company classifies as a current asset those retainages that are expected to be billed in the next twelve months. As of
December 31, 2019 and 2018, no amounts were determined to be uncollectible.
Inventory
Inventories, which consist primarily of PV solar panels, batteries and related accessories, are stated at the lower of cost
(“first-in, first-out” method) or net realizable value (determined as the estimated selling prices in the ordinary course of
business, less reasonably predictable costs of completion, disposal, and transportation). Provisions have been made to reduce
the carrying value of inventory to the net realizable value.
Prepaid Expenses
Prepaid expenses consist primarily of short-term prepaid expenditures that will amortize within one year.
Federal ESPC Receivable
Federal ESPC receivable represents the amount to be paid by various federal government agencies for work performed and
earned by the Company under specific ESPCs. The Company assigns certain of its rights to receive those payments to third-
parties that provide construction and permanent financing for such contracts. Upon completion and acceptance of the project by
the government, typically within 24 to 36 months of construction commencement, the assigned ESPC receivable from the
government and corresponding ESPC liability are eliminated from the Company’s consolidated financial statements.
Project Development Costs
The Company capitalizes as project development costs only those costs incurred in connection with the development of
energy projects, primarily direct labor, interest costs, outside contractor services, consulting fees, legal fees and travel, if
incurred after a point in time where the realization of related revenue becomes probable. Project development costs incurred
54 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
prior to the probable realization of revenue are expensed as incurred. The Company classifies as a current asset those project
development efforts that are expected to proceed to construction activity in the twelve months that follow. The Company
periodically reviews these balances and writes off any amounts where the realization of the related revenue is no longer
probable. Project development costs of $1,080 and $639 were included in other long-term assets as of December 31, 2019 and
2018, respectively.
Property and Equipment
Property and equipment consists primarily of office and computer equipment, and is recorded at cost. Major additions and
improvements are capitalized as additions to the property and equipment accounts, while replacements, maintenance and repairs
that do not improve or extend the life of the respective assets, are expensed as incurred. Depreciation and amortization of
property and equipment are computed on a straight-line basis over the following estimated useful lives:
Asset Classification
Furniture and office equipment . . . . . . . . . . . . . . . . . . . . . . . . Five years
Computer equipment and software costs. . . . . . . . . . . . . . . . . Three to five years
Leasehold improvements. . . . . . . . . . . . . . . . . . . . . . . . . . . . . Lesser of term of lease or five years
Automobiles . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Five years
Land. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unlimited
Estimated Useful Life
Gains or losses on disposal of property and equipment are reflected in selling, general and administrative expenses in the
consolidated statements of income.
Energy Assets
Energy assets consist of costs of materials, direct labor, interest costs, outside contract services, deposits and project
development costs incurred in connection with the construction of small-scale renewable energy plants that the Company owns.
These amounts are capitalized and amortized to cost of revenues in the Company’s consolidated statements of income on a
straight line basis over the lives of the related assets or the terms of the related contracts.
The Company capitalizes interest costs relating to construction financing during the period of construction. Capitalized
interest is included in energy assets, net, in the Company’s consolidated balance sheets. Capitalized interest is amortized to cost
of revenues in the Company’s consolidated statements of income on a straight line basis over the useful life of the associated
energy asset. The amount of interest capitalized for the years ended December 31, 2019, 2018 and 2017 was $2,966, $3,817 and
$4,256, respectively.
Routine maintenance costs are expensed in the current year’s consolidated statements of income to the extent that they do
not extend the life of the asset. Major maintenance, upgrades and overhauls are required for certain components of the
Company’s assets. In these instances, the costs associated with these upgrades are capitalized and are depreciated over the
shorter of the remaining life of the asset or the period until the next required major maintenance or overhaul.
Included in energy assets are financing lease assets and accumulated depreciation of financing lease assets. For additional
information see the Sale-Leaseback section below and Note 8.
The Company evaluates its long-lived assets for impairment as events or changes in circumstances indicate the carrying
value of these assets may not be fully recoverable. Examples of such triggering events applicable to the Company’s assets
include a significant decrease in the market price of a long-lived asset or asset group or a current-period operating or cash flow
loss combined with a history of operating or cash flow losses or a projection or forecast that demonstrates continuing losses
associated with the use of a long-lived asset or asset group.
The Company evaluates recoverability of long-lived assets to be held and used by estimating the undiscounted future cash
flows before interest associated with the expected uses and eventual disposition of those assets. When these comparisons
indicate that the carrying value of those assets is greater than the undiscounted cash flows, the Company recognizes an
impairment loss for the amount that the carrying value exceeds the fair value.
From time to time, the Company has applied for and received cash grant awards from the U.S. Treasury Department (the
“Treasury”) under Section 1603 of the American Recovery and Reinvestment Act of 2009 (the “Act”). The Act authorized the
Treasury to make payments to eligible persons who place in service qualifying renewable energy projects. The grants are paid
in lieu of investment tax credits. All of the cash proceeds from the grants were used and recorded as a reduction in the cost
55
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
basis of the applicable energy assets. If the Company disposes of the property, or the property ceases to qualify as specified
energy property, within five years from the date the property is placed in service, then a prorated portion of the Section 1603
payment must be repaid.
The Company last received a Section 1603 grant during the year ended December 31, 2014. No further Section 1603 grant
payments are expected to be received as the program has expired and no repayments will be required.
During the year ended December 31, 2019, the Company received grant proceeds of $784 from the Canadian government
in connection with the construction of one of the Company’s energy assets in Canada.
For tax purposes, the Section 1603 payments are not included in federal and certain state taxable income and the basis of
the property is reduced by 50% of the payment received. Deferred grant income of $6,086 and $6,637 in the accompanying
consolidated balance sheets at December 31, 2019 and 2018, respectively, represents the benefit of the basis difference to be
amortized to income tax expense over the life of the related property.
The Company has historically received cash rebates from utility companies, which were accounted for as reductions in the
book value of the related energy assets. The rebates were one-time payments based on the cost and efficiency of the installed
units, and are earned upon installation and inspection by the utility. The payments are not related to, or subject to adjustment
based on, future operating performance. No rebates were received during the years ended December 31, 2019, 2018 and 2017.
Deferred Financing Fees
Deferred financing fees relate to the external costs incurred to obtain financing for the Company. Deferred financing fees
are amortized over the respective term of the financing using the effective interest method, with the exception of the Company’s
revolving credit facility and construction loans, as discussed in Note 9, for which deferred financing fees are amortized on a
straight-line basis over the term of the agreement. Deferred financing fees are presented on the consolidated balance sheets as a
reduction to long-term debt and capital lease liabilities.
Goodwill and Intangible Assets
The Company has classified as goodwill the amounts paid in excess of fair value of the net assets (including tax attributes)
of companies acquired in purchase transactions. The Company has recorded intangible assets related to customer contracts, customer
relationships, non-compete agreements, trade names and technology, each with defined useful lives. The Company assesses the
impairment of goodwill and intangible assets that have indefinite lives on an annual basis (December 31st) and whenever events
or changes in circumstances indicate that the carrying value of the asset may not be recoverable.
Goodwill is reviewed for impairment annually and whenever events or changes in circumstances indicate that the carrying
value of an asset may not be recoverable. The process of evaluating the potential impairment of goodwill requires significant
judgment. The Company regularly monitors current business conditions and other factors including, but not limited to, adverse
industry or economic trends, restructuring actions and projections of future results. The Company estimates the reporting units
fair value and compares it with the carrying value of the reporting unit, including goodwill. If the fair value is greater than the
carrying value of its reporting unit, no impairment is recorded. Fair value is determined using both an income approach and a
market approach. The estimates and assumptions used in the Company’s calculations include revenue growth rates, expense
growth rates, expected capital expenditures to determine projected cash flows, expected tax rates and an estimated discount rate
to determine present value of expected cash flows. These estimates are based on historical experiences, the Company’s
projections of future operating activity and its weighted-average cost of capital. If the fair value is less than the carrying value,
an impairment loss is recognized for the amount that the carrying amount of a reporting unit, including goodwill, exceeds its
fair value, limited to the total amount of goodwill allocated to that reporting unit. The impairment charge would be recorded to
earnings in the consolidated statements of income. Judgment is required in determining whether an event has occurred that
may impair the value of goodwill or identifiable intangible assets.
Acquired intangible assets other than goodwill that are subject to amortization include customer contracts and customer
relationships, as well as software/technology, trade names and non-compete agreements. The intangible assets are amortized
over periods ranging from one to fifteen years from their respective acquisition dates. The Company evaluates its intangible
assets for impairment consistent with, and part of, their long-lived assets evaluation, as discussed in Energy Assets above.
See Notes 4 and 5 for additional disclosures.
56 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Leases
As of January 1, 2019, the Company adopted Accounting Standard Update (“ASU”) 2016-02, Leases (Topic 842) and, along
with the standard, elected to take the practical expedient that the Company will not reassess lease classifications at adoption.
Accordingly, the Company’s sales-leaseback arrangements entered into as of December 31, 2018 will remain under the previous
guidance. See Note 7 and 8 for additional information on these sale-leasebacks.
All significant lease arrangements are recognized at lease commencement. Operating lease right-of-use (“ROU”) assets and
lease liabilities are recognized at commencement. An ROU asset and corresponding lease liability are not recorded for leases with
an initial term of 12 months or less (short term leases) as the Company recognizes lease expense for these leases as incurred over
the lease term.
ROU assets represent the Company’s right to use an underlying asset during the reasonably certain lease term and lease
liabilities represent the Company’s obligation to make lease payments arising from the lease. The Company’s lease terms may
include options to extend or terminate the lease when it is reasonably certain that the Company will exercise that option. Operating
lease ROU assets and liabilities are recognized at commencement date based on the present value of lease payments over the lease
term. The Company uses its incremental borrowing rate, which is updated annually or when a significant event occurs that would
indicate a significant change in rates, based on the information available at commencement date, in determining the present value
of lease payments. The operating lease ROU asset also includes any lease payments related to initial direct cost and prepayments
and excludes lease incentives. Lease expense is recognized on a straight-line basis over the lease term.
The Company has historical leases under ASC 840, Leases, which may have lease and non-lease components. Upon adoption
of Topic 842, the Company has elected to continue to account for these historical leases as a single component, as permitted by
Topic 842. As of January 1, 2019, as it relates to all prospective leases, the Company allocates consideration to lease and non-
lease components based on pricing information in the respective lease agreement, or, if this information is not available, the
Company makes a good faith estimate based on the available pricing information at the time of the lease agreement. See Note 8
for additional discussion on the Company’s leases.
Other Assets
Other assets consist primarily of notes and contracts receivable due to the Company from various customers and non-
current restricted cash. Other assets also include the fair value of derivatives determined to be assets, the non-current portions of
project development costs, accounts receivable retainages, sale-leaseback deferred loss and deferred contract costs.
Asset Retirement Obligations
The Company recognizes a liability for the fair value of required asset retirement obligations (“AROs”) when such
obligations are incurred. The Company records, as liabilities, the fair value of the AROs on a discounted basis when incurred
and reasonably estimated which is typically at the time the assets are installed or operating. Over time, the liabilities increase
due to the change in present value, and initial capitalized costs are depreciated over the useful life of the related assets. Upon
satisfaction of the ARO conditions, any difference between the recorded ARO liability and the actual retirement cost incurred is
recognized as an operating gain or loss in the consolidated statements of income. See Note 7 for additional disclosures on the
Company’s AROs.
Federal ESPC Liabilities
Federal ESPC liabilities, for both projects and energy assets, represent the advances received from third-parties under
agreements to finance certain ESPC projects with various federal government agencies. For projects related to the construction
or installation of certain energy savings equipment or facilities developed for the government customer, upon completion and
acceptance of the project by the government, typically within 24 to 36 months of construction commencement, the ESPC
receivable from the government and corresponding ESPC liability is eliminated from the Company’s consolidated balance
sheets. Until recourse to the Company ceases for the ESPC receivables transferred to the investor, upon final acceptance of the
work by the government customer, the Company remains the primary obligor for financing received.
For small-scale energy assets developed for a government customer that the Company owns and operates, upon final
acceptance of the work by the government customer, the Company remains the primary obligor for financing received until the
liability is eliminated from the Company’s consolidated balance sheets as contract payments assigned by the customer are
transferred to the investor.
57 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Sale-Leaseback
The Company has previously entered into sale-leaseback arrangements that provided for the sale of solar photovoltaic
(“solar PV”) projects to a third-party investor and the simultaneous leaseback of the projects, which the Company then operates
and maintains, recognizing revenue through the sale of the electricity and solar renewable energy credits generated by these
projects.
In sale-leaseback arrangements, the Company first determines whether the solar PV project under the sale-leaseback
arrangement is “integral equipment.” A solar PV project is determined to be integral equipment when the cost to remove the
project from its existing location, including the shipping and reinstallation costs of the solar PV project at the new site,
including any diminution in fair value, exceeds 10% of the fair value of the solar PV project at the time of its original
installation. When the leaseback arrangement expires, the Company has the option to purchase the solar PV project for the then
fair market value or, in certain circumstances, renew the lease for an extended term. All solar PV projects sold to date under the
sale-leaseback program have been determined by the Company not to be integral equipment as the cost to remove the project
from its existing location would not exceed 10% of its original fair value.
For solar PV projects that the Company has determined not to be integral equipment, the Company then determines if the
leaseback should be classified as a capital lease or an operating lease. All solar PV projects sold to date under the sale-leaseback
program have been determined by the Company to be capital leases. For leasebacks classified as capital leases, the Company
initially records a capital lease asset and capital lease obligation in its consolidated balance sheets equal to the lower of the
present value of the Company’s future minimum leaseback payments or the fair value of the solar PV project. For capital
leasebacks, the Company defers any gain or loss, representing the excess or shortfall of cash received from the investor
compared to the net book value of the asset in the Company’s consolidated balance sheets at the time of the sale. The Company
records the long term portion of any deferred gain or loss in other liabilities and other assets, respectively, and the current
portion of any deferred gain and loss in accrued expenses and other current liabilities and prepaid expenses and other current
assets, respectively, in its consolidated balance sheets and amortizes the deferred amounts over the lease term in cost of
revenues in its consolidated statements of income.
In accordance with the Company’s adoption of Topic 842, sale-leaseback transactions shall be accounted for as a financing
liability on a prospective basis as the Company retains control of the underlying assets. As these transactions meet the criteria of
a failed sale, the proceeds received in prospective transactions, as of January 1, 2019, are accounted for as a long term financing
liability with interest rates determined based upon the underlying details of each specific transaction. See Note 8 and Note 9 for
further discussion and details of sale lease-back and financing liability transactions.
Other Liabilities
Other liabilities consist primarily of the long-term portion of deferred revenue related to multi-year operation and
maintenance contracts which expire at various dates through 2033. Other liabilities also include the fair value of derivatives and
the long-term portions of sale-leaseback deferred gains. See Note 19 for additional derivative disclosures.
Revenue Recognition
The Company derives revenues from energy efficiency and renewable energy products and services. Energy efficiency
products and services include the design, engineering, and installation of equipment and other measures to improve the
efficiency, and control the operation, of a facility’s energy infrastructure. Renewable energy products and services include the
construction of small-scale plants that produce electricity, gas, heat or cooling from renewable sources of energy, the sale of
such electricity, gas, heat or cooling from plants that the Company owns, and the sale and installation of solar energy products
and systems. Below is a description of the Company’s primary lines of business.
Projects - The Company’s principal service relates to energy efficiency projects, which entails the design, engineering and
installation of, and assisting with the arranging of financing for an ever-increasing array of innovative technologies and
techniques to improve the energy efficiency, and control the operation, of a building’s energy- and water- consuming systems.
In certain projects, the Company also designs and constructs for a customer a central plant or cogeneration system providing
power, heat and/or cooling to a building, or a small-scale plant that produces electricity, gas, heat or cooling from renewable
sources of energy.
Under ASU 2014-09, Revenue from Contracts with Customers (Topic 606) the Company recognizes revenue from the
installation or construction of projects over time using the cost-based input method. The Company uses the total costs incurred
on the project relative to the total expected costs to account for the satisfaction of the performance obligation.
58 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
When the estimate on a contract indicates a loss, or claims against costs incurred reduce the likelihood of recoverability of
such costs, the Company records the entire estimated loss in the period the loss becomes known.
Operations & Maintenance (“O&M”) - After an energy efficiency or renewable energy project is completed, the Company
often provides ongoing O&M services under a multi-year contract. These services include operating, maintaining and repairing
facility energy systems such as boilers, chillers and building controls, as well as central power and other small-scale plants. For
larger projects, the Company frequently maintains staff on-site to perform these services.
Maintenance revenue is recognized using the input method to recognize revenue. In most cases, O&M fees are fixed annual
fees. Because the Company is on-site to perform O&M services, the services are typically a distinct series of promises, and
those services have the same pattern of transfer to the customer (i.e., evenly over time), the Company records the revenue on a
straight-line basis. Some O&M service contract fees are billed on time expended. In those cases, revenue is recorded based on
the time expended in that month.
Energy Assets - The Company’s service offerings also includes the sale of electricity, processed renewable gas fuel, heat or
cooling from the portfolio of assets that the Company owns and operates. The Company has constructed and is currently
designing and constructing a wide range of renewable energy plants using landfill gas (“LFG”), wastewater treatment biogas,
solar, biomass, other bio-derived fuels, wind and hydro sources of energy. Most of the Company’s renewable energy projects to
date have involved the generation of electricity from solar PV and LFG or the sale of processed LFG. The Company purchases
the LFG that otherwise would be combusted or vented, processes it, and either sells it or uses it in its energy plants. The
Company has also designed and built, as well as owns, operates and maintains, plants that take biogas generated in the
anaerobic digesters of wastewater treatment plants and turns it into renewable natural gas that is either used to generate energy
on-site or that can be sold through the nation’s natural gas pipeline grid. Where the Company owns and operates energy
producing assets, the Company typically enters into a long-term power purchase agreement (“PPA”) for the sale of the energy.
Many of the Company’s energy assets also produce environmental attributes, including renewable energy credits (“RECs”) and
Renewable Identification Numbers (“RINs”). In most cases, the Company sells these attributes under separate agreements with
third parties other than the PPA customer.
The Company recognizes revenues from the sale and delivery of the energy output from renewable energy plants, over time
as produced and delivered to the customer, in accordance with specific PPA contract terms. Environmental attributes revenue is
recognized at a point in time, when the environmental attributes are transferred to the customer in accordance with the transfer
protocols of the environmental attributes market that the Company operates in. In those cases where environmental attributes
are sold to the same customer as the energy output, the Company records revenue monthly for both the energy output and the
environmental attribute output, as generated and delivered to the customer. The Company has determined that certain power
purchase agreements contain a lease component in accordance with ASC 840, Leases, prior to adoption of Topic 842. The
Company recognized $8,189, $7,238 and $3,409 of operating lease revenue under these agreements during the years ended
December 31, 2019, 2018 and 2017, respectively.
Other - The Company’s service and product offerings also include integrated-PV and consulting and enterprise energy
management services.
The Company recognizes revenues from delivery of engineering, consulting services and enterprise energy management
services over time. For the sale of solar materials, revenue is recognized at a point in time when the Company has transferred
physical control of the asset to the customer upon shipment.
To the extent a contract is deemed to have multiple performance obligations, the Company allocates the transaction price of
the contract to each performance obligation using its best estimate of the standalone selling price of each distinct good or
service in the contract.
Billings in excess of cost and estimated earnings represents advanced billings on certain construction contracts. Costs and
estimated earnings in excess of billings represent certain amounts under customer contracts that were earned and billable but
not invoiced.
Results for reporting periods beginning January 1, 2018 are presented under Topic 606, while prior period amounts are not
adjusted and continue to be reported under ASC 605, Revenue Recognition.
59
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Cost of Revenues
Cost of revenues include the cost of labor, materials, equipment, subcontracting and outside engineering that are required
for the development and installation of projects, as well as preconstruction costs, sales incentives, associated travel, inventory
obsolescence charges, amortization of intangible assets related to customer contracts, and, if applicable, costs of procuring
financing. A majority of the Company’s contracts have fixed price terms; however, in some cases the Company negotiates
protections, such as a cost-plus structure, to mitigate the risk of rising prices for materials, services and equipment.
Cost of revenues also include the costs of maintaining and operating the small-scale renewable energy plants that the
Company owns, including the cost of fuel (if any) and depreciation charges.
Income Taxes
The Company provides for income taxes based on the liability method. The Company provides for deferred income taxes
based on the expected future tax consequences of differences between the financial statement basis and the tax basis of assets
and liabilities calculated using the enacted tax rates in effect for the year in which the differences are expected to be reflected in
the tax return.
The Company accounts for uncertain tax positions using a “more-likely-than-not” threshold for recognizing and resolving
uncertain tax positions. The evaluation of uncertain tax positions is based on factors that include, but are not limited to, changes
in tax law, the measurement of tax positions taken or expected to be taken in tax returns, the effective settlement of matters
subject to audit, new audit activity and changes in facts or circumstances related to a tax position. The Company evaluates
uncertain tax positions on a quarterly basis and adjusts the level of the liability to reflect any subsequent changes in the relevant
facts surrounding the uncertain positions.
The Company’s liabilities for uncertain tax positions can be relieved only if the contingency becomes legally extinguished
through either payment to the taxing authority or the expiration of the statute of limitations, the recognition of the benefits
associated with the position meet the “more-likely-than-not” threshold or the liability becomes effectively settled through the
examination process.
The Company considers matters to be effectively settled once the taxing authority has completed all of its required or
expected examination procedures, including all appeals and administrative reviews; the Company has no plans to appeal or
litigate any aspect of the tax position; and the Company believes that it is highly unlikely that the taxing authority would
examine or re-examine the related tax position. The Company also accrues for potential interest and penalties, related to
unrecognized tax benefits in income tax expense.
The Company has presented all deferred tax assets and liabilities as net and noncurrent on its consolidated balance sheets
as of December 31, 2019 and 2018, respectively.
See Note 10 for additional information on the Company’s income taxes.
Foreign Currency
The local currency of the Company’s foreign operations is considered the functional currency of such operations. All assets
and liabilities of the Company’s foreign operations are translated into U.S. dollars at year-end exchange rates. Income and
expense items are translated at average exchange rates prevailing during the year. Translation adjustments are accumulated as a
separate component of stockholders’ equity. Foreign currency translation gains and losses are reported in the consolidated
statements of comprehensive income. Foreign currency transaction gains and losses are reported in the consolidated statements
of income.
Financial Instruments
Financial instruments consist of cash and cash equivalents, restricted cash, accounts and notes receivable, long-term
contract receivables, accounts payable, accrued expenses, financing lease assets and liabilities, contingent considerations, short-
and long-term borrowings, make-whole provisions, interest rate swaps, and commodity swaps. Because of their short maturity,
the carrying amounts of cash and cash equivalents, restricted cash, accounts and notes receivable, accounts payable, accrued
expenses, certain contingent considerations, and short-term borrowings approximate fair value.
60 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Stock-Based Compensation Expense
Stock-based compensation expense results from the issuance of shares of restricted common stock and grants of stock
options to employees, directors, outside consultants and others. The Company recognizes the costs associated with restricted
stock option grants, and employee stock purchases made via the Company’s Employee Stock Purchase Plan (the “ESPP”) using
the fair value recognition provisions of ASC 718, Compensation - Stock Compensation, on a straight-line basis over the vesting
period of the awards. Certain option grants have performance conditions that must be achieved prior to vesting and are
expensed based on the expected achievement at each reporting period. Stock-based compensation expense is also recognized in
association with employee stock purchases related to the Company’s ESPP.
Stock-based compensation expense is recognized based on the grant-date fair value. The Company estimates the fair value
of the stock-based awards, including stock options, using the Black-Scholes option-pricing model. Determining the fair value of
stock-based awards requires the use of highly subjective assumptions, including the fair value of the common stock underlying
the award, the expected term of the award and expected stock price volatility.
The assumptions used in determining the fair value of stock-based awards represent management’s estimates, which
involve inherent uncertainties and the application of management judgment. As a result, if factors change, and different
assumptions are employed, the stock-based compensation could be materially different in the future. The risk-free interest rates
are based on the U.S. Treasury yield curve in effect at the time of grant, with maturities approximating the expected life of the
stock options.
The Company has no history of paying dividends. Additionally, as of each of the grant dates, there was no expectation that
the Company would pay dividends over the expected life of the options. The expected life of the awards is estimated based
upon the period stock option holders will retain their vested options before exercising them. The Company uses
historical volatility as the expected volatility assumption required in the Black-Scholes model.
The Company recognizes compensation expense for only the portion of options that are expected to vest. If there are any
modifications or cancellations of the underlying invested securities or the terms of the stock option, it may be necessary to
accelerate, increase or cancel any remaining unamortized stock-based compensation expense. As a result of the adoption of
ASU 2016-09, Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting,
during fiscal year 2017, no significant changes were made to the Company’s accounting for forfeitures. Upon adoption the
Company recorded a $4,000 deferred tax asset and corresponding credit to retained earnings for excess tax benefits that had not
previously been recognized because the related tax deductions had not reduced taxes payable.
The Company also accounts for equity instruments issued to non-employee directors and consultants at fair value. All
transactions in which goods or services are the consideration received for the issuance of equity instruments are accounted for
based on the fair value of the equity instruments to be issued. The measurement date of the fair value of the equity instrument
issued is the grant date, which is the date that the Company and the grantee reach a mutual understanding of the key terms and
conditions of the award.
No awards to individuals who were not either an employee or director of the Company occurred during the years ended
December 31, 2019, 2018 and 2017.
Fair Value Measurements
The Company follows the guidance related to fair value measurements for all of its non-financial assets and non-financial
liabilities, except for those recognized at fair value in the financial statements at least annually. These assets include goodwill
and long-lived assets measured at fair value for impairment assessments, and non-financial assets and liabilities initially
measured at fair value in a business combination.
The Company’s financial instruments consist of cash and cash equivalents, restricted cash, accounts and notes receivable,
long-term contract receivables, accounts payable, accrued expenses, financing lease assets and liabilities, contingent
considerations, short- and long-term borrowings, make-whole provisions, interest rate swaps, and commodity swaps. Because
of their short maturity, the carrying amounts of cash and cash equivalents, restricted cash, accounts and notes receivable,
accounts payable, accrued expenses, certain contingent considerations, and short-term borrowings approximate fair value.
The carrying value of long-term variable-rate debt approximates fair value. As of December 31, 2019, the carrying value of the
Company’s long-term debt exceeds its fair value of $309,377 by approximately $1,869. Fair value of the Company’s debt is
based on quoted market prices or on rates available to the Company for debt with similar terms and maturities, which are level
two inputs of the fair value hierarchy, as defined in Note 18.
61 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
The Company accounts for its interest rate swaps and commodity swaps as derivative financial instruments in accordance
with the related guidance. Under this guidance, derivatives are carried on the Company’s consolidated balance sheets at fair
value. The fair value of the Company’s interest rate and commodity swaps are determined based on observable market data in
combination with expected cash flows for each instrument. The Company accounts for its make-whole provision features as
embedded derivatives in accordance with related guidance. Under this guidance, the derivative is bifurcated from its host
contract and recorded on the Company’s consolidated balance sheets at fair value. The fair value of the Company’s make-
whole provisions are determined based on observable market data and a with and without model.
The consideration for the Company’s acquisitions often includes future payments that are contingent upon the occurrence
of a particular event. The Company records a contingent consideration obligation for such contingent consideration payments at
fair value on the acquisition date. The Company estimates the acquisition date fair value of contingent consideration obligations
through valuation models that incorporate probability adjusted assumptions related to the achievement of the milestones and the
likelihood of making related payments. Each period the Company revalues the contingent consideration obligations associated
with the acquisition to fair value and records changes in the fair value within the selling, general and administrative expenses
line in our consolidated statements of income. Increases or decreases in the fair value of the contingent consideration
obligations can result from changes in assumed discount periods and rates, changes in the assumed timing and amount of
revenue and expense estimates and changes in assumed probability with respect to the attainment of certain financial and
operational metrics, among others. Significant judgment is employed in determining these assumptions as of the acquisition
date and for each subsequent period. Accordingly, future business and economic conditions, as well as changes in any of the
assumptions described above, can materially impact the fair value of contingent consideration recorded at each reporting
period. However, deferred consideration related to certain holdbacks and completion payments are considered short-term in
nature. These amounts are recorded at full value and are only revalued if one of those underlying assumptions changes.
See Note 18 for additional information related to fair value measurements.
Share Repurchase Program
In April 2016, the Company’s Board of Directors authorized the repurchase of up to $10,000 of the Company’s Class A
common stock from time to time on the open market or in privately negotiated transactions. The Company’s Board of Directors
authorized an increase in the Company’s share repurchase authorization to $15,000 of the Company's Class A common stock in
February 2017 and to $17,553 of the Company's Class A common stock in August 2019. The timing and amount of any shares
repurchased will be determined by the Company’s management based on its evaluation of market conditions and other factors.
Any repurchased shares will be available for use in connection with its stock plans and for other corporate purposes. The
repurchase program has and will be funded using the Company’s working capital and borrowings under its revolving line of
credit. The Company accounts for share repurchases using the cost method. Under this method, the cost of the share repurchase
is recorded entirely in treasury stock, a contra equity account. During the year ended December 31, 2019, the Company
repurchased 10.3 shares of common stock in the amount of $144, net of fees of immaterial amounts. During the year ended
December 31, 2018, the Company repurchased 218 shares of common stock in the amount of $1,839, net of fees of $9.
Derivative Financial Instruments
In the normal course of business, the Company utilizes derivatives contracts as part of its risk management strategy to
manage exposure to market fluctuations in interest and commodity rates. These instruments are subject to various credit and
market risks. Controls and monitoring procedures for these instruments have been established and are routinely reevaluated.
Credit risk represents the potential loss that may occur because a party to a transaction fails to perform according to the terms of
the contract. The measure of credit exposure is the replacement cost of contracts with a positive fair value. The Company seeks
to manage credit risk by entering into financial instrument transactions only through counterparties that the Company believes
to be creditworthy.
Market risk represents the potential loss due to the decrease in the value of a financial instrument caused primarily by
changes in interest rates and commodity prices. The Company seeks to manage market risk by establishing and monitoring
limits on the types and degree of risk that may be undertaken. As a matter of policy, the Company does not use derivatives for
speculative purposes. The Company considers the use of derivatives with all financing transactions to mitigate risk.
The Company recognizes cash flows from derivative instruments as operating activities in the consolidated statements of
cash flows. The Company recognizes all changes in fair value on interest rate swaps designated as effective cash flow hedges in
the Company’s consolidated statements of comprehensive income. Changes in fair value on derivatives not designated as
hedges are recognized in the Company’s consolidated statements of income.
62
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
In July 2018, the Company made a prepayment on one of its term loans that had a related interest rate swap that was
designated as a hedging instrument, which was canceled and de-designated as a hedge instrument. The Company does not have
a history of prepaying its debt facilities and is not planning a prepayment or a forced prepayment of any of the Company’s
hedged debt facilities. See Note 19 for additional information concerning the de-designation of this interest rate swap.
In June 2018, the Company entered into a term loan agreement, discussed in Note 9, that contained an interest make-whole
provision. In August 2018, the Company signed a joinder to the above agreement, which added another series of notes to the
term loan that also contained an interest make-whole provision. The Company determined that these provisions fulfill the
requirements of an embedded derivative instrument that were required to be bifurcated from its host agreement. The instrument
is revalued periodically and the changes in fair value are recognized as either gains or losses in other expenses, net in the
Company’s consolidated statements of income.
See Notes 18 and 19 for additional information on the Company’s derivative instruments.
Earnings Per Share
Basic earnings per share is calculated using the Company’s weighted-average outstanding common shares, including
vested restricted shares. When the effects are not anti-dilutive, diluted earnings per share is calculated using the weighted-
average outstanding common shares; the dilutive effect of convertible preferred stock, under the “if converted” method; and the
treasury stock method with regard to warrants and stock options; all as determined under the treasury stock method.
Net income attributable to common shareholders . . . . . . . . . . . . . . . . . . $
44,436
$
37,984
$
Basic weighted-average shares outstanding . . . . . . . . . . . . . . . . . . . . . . .
Effect of dilutive securities:
46,586
45,729
Stock options . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted weighted-average shares outstanding . . . . . . . . . . . . . . . . . . . . .
1,188
47,774
1,102
46,831
37,491
45,509
239
45,748
2019
Year Ended December 31,
2018
2017
For the years ended December 31, 2019, 2018 and 2017, 806, 692 and 2,560 shares of common stock, respectively, related to
stock options were excluded from the calculation of dilutive shares since the inclusion of such shares would be anti-dilutive.
Variable Interest Entities
Certain contracts are executed jointly through partnership and joint venture arrangements with unrelated third parties. The
arrangements are often formed for the single business purpose of executing a specific project and allow the Company to share
risks and/or secure specialty skills required for project execution.
The Company evaluates each partnership and joint venture at inception to determine if it qualifies as a VIE under ASC 810,
Consolidation. A variable interest entity is an entity used for business purposes that either (a) does not have equity investors with
voting rights or (b) has equity investors who are not required to provide sufficient financial resources for the entity to support its
activities without additional subordinated financial support. Upon the occurrence of certain events outlined in ASC 810, the
Company reassesses its initial determination of whether the partnership or joint venture is a VIE.
The Company also evaluates whether it is the primary beneficiary of each VIE and consolidates the VIE if the Company has
both (a) the power to direct the economically significant activities of the entity and (b) the obligation to absorb losses of, or the
right to receive benefits from, the entity that could potentially be significant to the VIE. The Company considers the contractual
agreements that define the ownership structure, distribution of profits and losses, risks, responsibilities, indebtedness, voting rights
and board representation of the respective parties in determining whether it qualifies as the primary beneficiary. The Company
also considers all parties that have direct or implicit variable interests when determining whether it is the primary beneficiary.
When the Company is determined to be the primary beneficiary, the VIE is consolidated. As required by ASC 810, management's
assessment of whether the Company is the primary beneficiary of a VIE is continuously performed.
The Company generally aggregates the disclosures of its VIEs based on certain qualitative and quantitative factors including
the purpose and design of the underlying VIEs, the nature of the assets in the VIE, and the type of involvement the Company has
with the VIE including its role and type of interest held in the VIE. As of December 31, 2019, all the VIEs that make up the
Company’s investment funds are similar in purpose, design, and the Company’s involvement and, as such, are aggregated in one
disclosure. See Note 11 and 12 for additional disclosures.
63
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Equity Method Investment
The Company has entered into four joint ventures and has determined they are not the primary beneficiaries using the
methodology previously described for variable interest entities. The Company does not consolidate the operations of these joint
ventures and treats the joint ventures as equity method investments. See Note 11 for additional information on the Company’s
equity method investments.
Redeemable Non-Controlling Interests
In each of September 2015, June 2017, June 2018, October 2018 and December 2019, the Company formed an investment
fund with a different third party investor which granted the applicable investor ownership interests in the net assets of certain of
the Company’s renewable energy project subsidiaries. The Company currently has five such investment funds each with a
different third party investor.
The Company entered into these agreements in order to finance the costs of constructing energy assets which are under
long-term customer contracts. The Company has determined that these entities qualify as VIEs and that it is the primary
beneficiary in the operational partnerships for accounting purposes. Accordingly, the Company will consolidate the assets and
liabilities and operating results of the entities in its consolidated financial statements. The Company will recognize the
investors’ share of the net assets of the subsidiaries as redeemable non-controlling interests in its consolidated balance sheets.
The Company has determined that the provisions in the contractual arrangements represent substantive profit-sharing
arrangements. The Company has further determined that the appropriate methodology for attributing income and loss to the
redeemable non-controlling interests each period is a balance sheet approach referred to as the hypothetical liquidation at book
value (“HLBV”) method. Under the HLBV method, the amounts of income and loss attributed to the redeemable non-
controlling interests in the consolidated statements of income reflect changes in the amounts the investors would hypothetically
receive at each balance sheet date under the liquidation provisions of the contractual agreements, assuming the net assets of this
funding structure were liquidated at recorded amounts. The investors’ non-controlling interest in the results of operations of this
funding structure is determined as the difference in the non-controlling interest’s claim under the HLBV method at the start and
end of each reporting period, after taking into account any capital transactions, such as contributions or distributions, between
the Company’s subsidiaries and the investors. The use of the HLBV methodology to allocate income to the redeemable non-
controlling interest holders may create volatility in the Company’s consolidated statements of income as the application of
HLBV can drive changes in net income available and loss attributable to the redeemable non-controlling interests from quarter
to quarter.
The Company classified the non-controlling interests with redemption features that are not solely within the control of the
Company outside of permanent equity on its consolidated balance sheets. The redeemable non-controlling interests will be
reported using the greater of their carrying value at each reporting date as determined by the HLBV method or the estimated
redemption values in each reporting period.
See Notes 11 and 12 for additional disclosures.
Recent Accounting Pronouncements
Intangibles-Goodwill and Other
In August 2018, the FASB issued ASU No. 2018-15, Intangibles - Goodwill and Other - Internal-Use-Software (Subtopic
350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service
Contract, which clarifies the accounting for implementation, setup, and upfront costs and aligns the requirements for
capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for
capitalizing implementation costs incurred to develop or obtain internal-use software. The new standard is effective for the
interim and annual periods beginning after December 15, 2019, with early adoption permitted, and can be applied either
retrospectively or prospectively. The Company adopted this guidance as of January 1, 2019 and the adoption did not have an
impact on the Company’s consolidated financial statements.
Derivatives and Hedging
In April 2019, the FASB issued ASU No. 2019-04, Codification Improvements to Topic 326, Financial Instruments - Credit
Losses, Topic 815, Derivatives and Hedging, and Topic 825, Financial Instruments, which, among other things, clarifies some
areas around partial-term fair value hedges, interest rate risk, the amortization of fair value hedge basis adjustments and their
disclosure, and some clarification of some matters related to transitioning to ASU No. 2017-12, which was adopted by the
64 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Company during the year ended December 31, 2018. For those that have already adopted ASU No. 2017-12, the new standard
is effective the first annual period beginning after the issuance date of ASU No. 2019-04, or as of January 1, 2020 for the
Company, with early adoption permitted. The Company is currently evaluating the impact of ASU No. 2019-04 on its
consolidated financial statements, but does not expect that the adoption of this guidance will have a significant impact on its
consolidated financial statements.
Fair Value Measurement
In August 2018, the FASB issued ASU 2018-13 Fair Value Measurement (Topic 820): Disclosure Framework—Changes to
the Disclosure Requirements for Fair Value Measurement, which modifies the disclosure requirements on fair value
measurements. ASU 2018-13 is effective for fiscal years beginning after December 15, 2019, including interim periods within
those fiscal years. The Company is currently evaluating the impact ASU 2018-13 on its consolidated financial statements, but
does not expect that the adoption of this guidance will have a significant impact on its consolidated financial statements.
Leases
In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842). The guidance in this ASU supersedes the leasing
guidance in Topic 840, Leases. Under the new guidance, the Company is electing to only recognize lease assets and lease
liabilities on the balance sheet for all leases with terms longer than 12 months. Leases will be classified as either finance or
operating, with classification affecting the pattern of expense recognition in the income statement. ASU 2016-02 is effective for
fiscal years beginning after December 15, 2018, including interim periods within those fiscal years.
On January 1, 2019, the Company adopted ASU 2016-02 using the modified retrospective approach of applying the new
standard at the adoption date. See Note 8 for the impact of the adoption and the new disclosures required by this standard.
In March 2019, the FASB issued ASU No. 2019-01, Leases (Topic 842): Codification Improvements, which provides
clarification and improvements to the previous issued guidance. The standard is effective for fiscal years beginning after
December 15, 2019 and interim periods within those fiscal years. The Company is currently evaluating the impact of ASU
2019-01 on its consolidated financial statements, but does not expect that the adoption of this guidance will have a significant
impact on its consolidated financial statements.
Accumulated Other Comprehensive Income
In February 2018, the FASB issued ASU No. 2018-02, Income Statement – Reporting Comprehensive Income (Topic 220):
Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income, to allow entities to reclassify the
income tax effects of tax reform legislation commonly referred to as the Tax Cuts and Jobs Act (the “Tax Act”) on items within
accumulated other comprehensive income to retained earnings. ASU 2018-02 is effective for fiscal years and interim periods
within those years beginning after December 15, 2018, and early adoption is permitted. The Company adopted the guidance as
of January 1, 2019. Upon adoption, the Company recognized an increase to retained earnings and a corresponding increase to
accumulated other comprehensive loss of $217.
Consolidations
In October 2018, the FASB issued ASU No. 2018-17, Consolidation (Topic 810), Targeted Improvements to Related Party
Guidance for Variable Interest Entities, which aligns the evaluation of whether a decision maker's fee is a variable interest with
the guidance in the primary beneficiary test by requiring the decision maker to consider an indirect interest in a VIE held by
related party under common control on a proportionate basis. The new standard is effective interim and annual periods
beginning after December 15, 2019, with early adoption permitted. The Company is currently evaluating the impact of ASU
2018-17 on its consolidated financial statements, but does not expect that the adoption of this guidance will have a significant
impact on its consolidated financial statements.
Credit Losses
In June 2016, the FASB issued ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit
Losses on Financial Instruments (ASU 2016-13), and a subsequent amendment to the initial guidance, ASU 2018-19
Codification Improvements to Topic 326, Financial Instruments—Credit Losses (collectively, Topic 326). Topic 326 requires
measurement and recognition of expected credit losses for financial assets held, which include, but are not limited to, trade and
other receivables. The new standard is effective for fiscal years beginning after December 15, 2019. The Company is currently
65
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
evaluating the impact of this guidance on its consolidated financial statements, but does not expect that the adoption of this
guidance will have a significant impact on its consolidated financial statements.
Income Taxes
In December 2019, the FASB issued ASU No. 2019-12, Simplifying the Accounting for Income Taxes, which simplifies
the accounting for income taxes, eliminates certain exceptions within ASC 740, Income Taxes, and clarifies certain aspects of
the current guidance to promote consistency among reporting entities. ASU 2019-12 is effective for the Company for the fiscal
year beginning after December 15, 2020. The Company is currently evaluating the impacts of the provisions of ASU 2019-12
on its financial statements and disclosures.
3. REVENUE FROM CONTRACTS WITH CUSTOMERS
Adoption
On January 1, 2018, the Company adopted ASU 2014-09, Revenue from Contracts with Customers, (Topic 606) using the
modified retrospective method applied to those contracts which were not completed as of December 31, 2017. Results for
reporting periods beginning January 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and
continue to be reported under the accounting standards in effect for the prior period. The Company recorded a net decrease to
beginning retained earnings of $4,454 on January 1, 2018 due to the cumulative impact of adopting Topic 606, as detailed
below.
January 1, 2018
As Reported
606 Adjustments
Adjusted
Balances
Assets:
Costs and estimated earnings in excess of billings . . .
Prepaid expenses and other current assets . . . . . . . . .
Deferred income taxes, net . . . . . . . . . . . . . . . . . . . . .
$
104,852
14,037
—
$
Liabilities:
Accrued expenses and other current liabilities
Deferred income taxes, net . . . . . . . . . . . . . . . . . . . . .
23,260
584
Shareholders' Equity:
$
(9,194)
4,343
1,003
1,190
(584)
95,658
18,380
1,003
24,450
—
Retained earnings . . . . . . . . . . . . . . . . . . . . . . . . . . . .
235,844
(4,454)
231,390
66 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
In accordance with Topic 606, the disclosure of the impact of adoption to the Company’s consolidated statements of
income and balance sheets was as follows:
Revenues . . . . . . . . . . . . . . . . .
Cost of revenues . . . . . . . . . . .
Gross profit . . . . . . . . . . . . . . .
Operating expenses:
Selling, general and
administrative expenses. . . . . .
Operating income . . . . . . . . . .
Other expenses, net . . . . . . . . .
Income before provision for
income taxes . . . . . . . . . . . . . .
Income tax (benefit) provision
Net income. . . . . . . . . . . . . . . .
Net loss attributable to
redeemable non-controlling
interests . . . . . . . . . . . . . . . . . .
Net income attributable to
common shareholders . . . . . . .
Basic income per share . . . . .
Diluted income per share . . .
Impact of changes in accounting policies
12/31/2019
Balances
without
adoption of
Topic 606
$ 871,409
701,397
170,012
Effect of
Change
Higher/
(Lower)
$
(4,476)
(2,582)
(1,894)
12/31/2018
Balances
without
adoption of
Topic 606
$ 784,316
610,229
174,087
Effect of
Change
Higher/
(Lower)
$
2,822
3,297
(475)
As Reported
$ 787,138
613,526
173,612
As Reported
$ 866,933
698,815
168,118
116,504
51,614
15,061
36,553
(3,748)
40,301
116,504
53,508
15,061
38,447
(3,256)
41,703
—
(1,894)
—
(1,894)
(492)
(1,402)
114,513
59,099
16,709
42,390
4,813
37,577
114,513
59,574
16,709
42,865
4,998
37,867
—
(475)
—
(475)
(185)
(290)
4,135
4,135
—
407
407
—
$
$
$
44,436
0.95
0.93
$
$
$
45,838
0.98
0.96
$
$
$
(1,402)
(0.03)
(0.03)
$
$
$
37,984
0.83
0.81
$
$
$
38,274
0.84
0.82
$
$
$
(290)
(0.01)
(0.01)
December 31, 2019
December 31, 2018
As
Reported
Balances
without
adoption of
Topic 606
Effect of
Change
Higher/
(Lower)
Balances
without
adoption of
Topic 606
Effect of Change
Higher/(Lower)
As Reported
Assets:
Costs and estimated
earnings in excess of
billings . . . . . . . . . . . . . . . . . $ 202,243
Prepaid expenses and other
current assets . . . . . . . . . . . .
29,424
$ 213,091
$ (10,848)
$
86,842
$
93,214
$
(6,372)
25,776
3,648
11,571
10,644
927
Liabilities:
Accrued expenses and other
current liabilities
Deferred income taxes, net .
Shareholders' Equity:
31,356
115
30,147
2,378
1,209
(2,263)
35,947
4,352
34,877
6,123
1,070
(1,771)
Retained earnings . . . . . . . .
314,459
320,605
(6,146)
269,806
274,550
(4,744)
The impact in revenue recognition due to the adoption of Topic 606 is primarily from the timing of revenue recognition for
uninstalled materials, amortization of contract acquisition costs over the contract term, and timing of revenue recognition from
renewable energy credits. See Note 2 for a summary of the Company’s significant policies for revenue recognition.
67 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Disaggregation of Revenue
The following table provides information about disaggregated revenue by line of business and geographical region, by
reportable segments, for the year ended December 31, 2019.
US Regions U.S. Federal
Canada
Non-Solar
DG
All Other
Total
Line of Business
Year ended December 31, 2019
Project revenue . . . . . . $
O&M revenue . . . . . . .
Energy assets. . . . . . . .
Other . . . . . . . . . . . . . .
Total revenues
$
321,973
15,753
24,897
2,437
365,060
Geographical Regions
Year ended December 31, 2019
United States . . . . . . . . $
Canada. . . . . . . . . . . . .
Other . . . . . . . . . . . . . .
Total revenues
$
364,987
—
73
365,060
$
$
$
$
240,656
41,599
3,652
1,519
287,426
287,426
—
—
287,426
$
$
$
$
27,995
5
3,306
6,604
37,910
3,007
34,830
73
37,910
$
$
$
$
9,221
9,183
65,365
914
84,683
84,683
—
—
84,683
$
$
$
$
11,219
169
822
79,644
91,854
75,302
201
16,351
91,854
$
$
$
$
611,064
66,709
98,042
91,118
866,933
815,405
35,031
16,497
866,933
The following table provides information about disaggregated revenue by line of business and geographical region, by
reportable segments, for the year ended December 31, 2018.
US Regions U.S. Federal
Canada
Non-Solar
DG
All Other
Total
Line of Business
Year ended December 31, 2018
Project revenue . . . . . . $
O&M revenue . . . . . . .
Energy assets. . . . . . . .
Other . . . . . . . . . . . . . .
Total revenues
$
296,226
17,814
18,442
1,862
334,344
Geographical Regions
Year ended December 31, 2018
United States . . . . . . . . $
Canada. . . . . . . . . . . . .
Other . . . . . . . . . . . . . .
Total revenues
$
334,344
—
—
334,344
$
$
$
$
202,286
39,250
4,062
711
246,309
246,309
—
—
246,309
$
$
$
$
29,571
37
2,604
6,770
38,982
2,557
36,425
—
38,982
$
$
$
$
4,550
8,135
69,599
371
82,655
82,655
—
—
82,655
$
$
$
$
12,420
—
1,069
71,359
84,848
68,883
303
15,662
84,848
$
$
$
$
545,053
65,236
95,776
81,073
787,138
734,748
36,728
15,662
787,138
For the years ended December 31, 2019 and 2018, approximately 92% and 93%, respectively, of revenue is recognized
over time, and the remainder is for products and services transferred at a point in time.
68 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Contract Balances
The following table provides information about receivables, contract assets and contract liabilities from contracts with
customers:
Accounts receivable, net. . . . . . . . . . . . . . . . . . . . .
Accounts receivable retainage, net . . . . . . . . . . . . .
Contract Assets:
Costs and estimated earnings in excess of billings.
Contract Liabilities:
Billings in excess of cost and estimated earnings. .
December 31, 2019
95,863
$
16,976
December 31, 2018
85,985
$
13,516
202,243
32,178
86,842
30,706
Accounts receivable retainage represents amounts due from customers, but where payments are withheld contractually
until certain construction milestones are met. Amounts retained typically range from 5% to 10% of the total invoice. The
Company classifies as a current asset those retainages that are expected to be billed in the next twelve months. Unbilled
revenue, presented as costs and estimated earnings in excess of billings, represent amounts earned and billable that were not
invoiced at the end of the fiscal period.
Contract assets represent the Company’s rights to consideration in exchange for services transferred to a customer that have
not been billed as of the reporting date. The Company’s rights to consideration are generally unconditional at the time its
performance obligations are satisfied.
At the inception of a contract, the Company expects the period between when it satisfies its performance obligations, and
when the customer pays for the services, will be one year or less. As such, the Company has elected to apply the practical
expedient which allows the Company to not adjust the promised amount of consideration for the effects of a significant
financing component, when a financing component is present.
When the Company receives consideration, or such consideration is unconditionally due, from a customer prior to
transferring goods or services to the customer under the terms of a sales contract, the Company records deferred revenue, which
represents a contract liability. Such deferred revenue typically results from billings in excess of costs incurred and advance
payments received on project contracts. As of December 31, 2019 and 2018, the Company classified $5,560 and $6,342,
respectively, as a non-current liability, included in other liabilities on the consolidated balance sheets, for those performance
obligations expected to be completed beyond the next twelve months.
The increase in contract assets for the year ended December 31, 2019 was primarily due to revenue recognized of
$535,021, offset in part by billings of approximately $431,717. The increase in contract liabilities was primarily driven by the
receipt of advance payments from customers, and related billings, exceeding recognition of revenue as performance obligations
were satisfied. For the year ended December 31, 2019, the Company recognized revenue of $75,070, and billed customers
$73,675 that was previously included in the beginning balance of contract liabilities. Changes in contract liabilities are also
driven by reclassifications to or from contract assets as a result of timing of customer payments.
The decrease in contract assets for the year ended December 31, 2018 was primarily due to billings of approximately
$510,470, offset in part by revenue recognized of $485,143. The increase in contract liabilities was primarily driven by the
receipt of advance payments from customers, and related billings, exceeding recognition of revenue as performance obligations
were satisfied. For the year ended December 31, 2018, The Company recognized revenue of $95,318, and billed customers
$80,007, that was previously included in the beginning balance of contract liabilities. Changes in contract liabilities are also
driven by reclassifications to or from contract assets as a result of timing of customer payments.
Contracts are often modified for a change in scope or other requirements. The Company considers contract modifications
to exist when the modification either creates new or changes the existing enforceable rights and obligations. Most of the
Company’s contract modifications are for goods or services that are not distinct from the existing performance obligations. The
effect of a contract modification on the transaction price, and the measure of progress for the performance obligation to which it
relates, is recognized as an adjustment to revenue (either as an increase or decrease) on a cumulative catchup basis.
69 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
The Company elected to utilize the modified retrospective transition practical expedient which allows the Company to
evaluate the impact of contract modifications as of the adoption date rather than evaluating the impact of the modifications at
the time they occurred prior to the adoption date.
Performance obligations
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 in ASC Topic 606. Performance obligations are satisfied as of a point in time or over time and are supported by
contracts with customers. For most of the Company’s contracts, there are multiple promises of goods or services. Typically, the
Company provides a significant service of integrating a complex set of tasks and components such as design, engineering,
construction management, and equipment procurement for a project contract. The bundle of goods and services are provided to
deliver one output for which the customer has contracted. In these cases, the Company considers the bundle of goods and
services to be a single performance obligation. The Company may also promise to provide distinct goods or services within a
contract, such as a project contract for installation of energy conservation measures and post-installation O&M services. In
these cases the Company separates the contract into more than one performance obligation. If a contract is separated into more
than one performance obligation, the Company allocates the total transaction price to each performance obligation in an amount
based on the estimated relative standalone selling prices of the promised goods or services underlying each performance
obligation.
Backlog - The Company’s remaining performance obligations (hereafter referred to as “backlog”) represent the
unrecognized revenue value of the Company’s contract commitments. The Company’s backlog may vary significantly each
reporting period based on the timing of major new contract commitments and the backlog may fluctuate with currency
movements. In addition, our customers have the right, under some circumstances, to terminate contracts or defer the timing of
the Company’s services and their payments to us. At December 31, 2019, the Company had backlog of approximately
$2,249,970. Approximately 28%, of our December 31, 2019 backlog is anticipated to be recognized as revenue in the next
twelve months and the remaining, thereafter. The remaining performance obligations relate primarily to the energy efficiency
and renewable energy construction projects, including the long-term O&M services related to these projects. The long-term
services have varying initial contract terms, up to 25 years.
The Company has applied the practical expedient for certain revenue streams to exclude the value of remaining
performance obligations for (i) contracts with an original expected term of one year or less or (ii) contracts for which the
Company recognizes revenue in proportion to the amount it has the right to invoice for services performed.
Contract acquisition costs
In connection with the adoption of Topic 606, the Company is required to account for certain acquisition costs over the life
of the contract, consisting primarily of commissions. Commission costs are incurred commencing at contract signing.
Commission costs are allocated across all performance obligations and deferred and amortized over the contract term on a
progress towards completion basis.
As of December 31, 2019 and 2018, included in other assets in the accompanying consolidated balance sheets, the
Company capitalized $1,735 and $927, respectively, in commission costs related to contracts that were not completed. For
contracts that have a duration of less than one year, the Company follows a practical expedient and expenses these costs when
incurred. During the years ended December 31, 2019 and 2018, the amortization of commission costs related to contracts were
not material and have been included in the accompanying consolidated statements of income.
The Company analyzed the impact of adoption of Topic 606 on the Company’s project development costs and determined
no change in the Company’s accounting policy was required. During the years ended December 31, 2019 and 2018, $35,172
and $15,672, respectively, of project development costs were recognized in the consolidated statements of income on projects
that converted to customer contracts.
No impairment charges in connection with the Company’s commission costs or project development costs were recorded
during the years ended December 31, 2019 and 2018.
4. BUSINESS ACQUISITIONS AND RELATED TRANSACTIONS
The Company accounts for acquisitions using the acquisition method in accordance with ASC 805, Business
Combinations. The purchase price for each has been allocated to the assets based on their estimated fair values at the date of
70 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
each acquisition as set forth in the table below. The excess purchase price over the estimated fair value of the net assets, which
are calculated using level 3 inputs per the fair value hierarchy as defined in Note 18, acquired has been recorded as goodwill.
Intangible assets, if identified, have been recorded and are being amortized over periods ranging from one to fifteen years. See
Note 5 for additional information.
Determining the fair value of certain assets and liabilities assumed is judgmental in nature and often involves the use of
significant estimates and assumptions. Certain amounts below are provisional based on our best estimates using information
available as of the reporting date. The Company is waiting for information to become available to finalize its valuation of
certain elements of these transactions. Specifically, the assigned values for energy assets, intangibles, and goodwill are
provisional in nature and subject to change upon the completion of the final valuation of such elements.
In January 2019, the Company completed an acquisition of a Massachusetts based solar operations and maintenance firm
for consideration of $1,294. The pro-forma effects of this acquisition on the Company’s operations are not material.
In December 2018, the Company completed an acquisition of certain assets of Washington, DC based mechanical,
electrical, plumbing, and fire protection design company, JVP Engineers, P.C. The consideration consisted of $2,326, of
which, $1,901 has been paid to date. The remaining balance is attributed to a contingent consideration holdback related to the
collection of certain receivables and will be be paid 15 months from the completion of the acquisition. No debt was assumed or
cash acquired in the transaction. The pro-forma effects of this acquisition on the Company’s operations are not material. During
the year ended December 31, 2018, the Company had a measurement period adjustment of $197, which was recorded as a
reduction to goodwill.
In December 2018, the Company completed an acquisition of certain assets of the Hawaii-based building science and
design engineering consulting firm, Chelsea Group Limited. The consideration consisted of $1,691 of cash and potential
contingent consideration of up to $2,000 based upon meeting certain future revenue targets over the next 5 years. The final
purchase price is subject to a net working capital adjustment, dependent on the level of working capital at the acquisition date,
that has not been finalized yet. The fair value of the contingent consideration was $555 as of the date of acquisition. No debt
was assumed or cash acquired in the transaction. The pro-forma effects of this acquisition on the Company’s operations are not
material. The value of the contingent consideration increased by $44 during the year ended December 31, 2018 to a ending
balance of $599 as of December 31, 2018. The value of the contingent consideration increased by $79 during the year ended
December 31, 2019 to a ending balance of $678 as of December 31, 2019. See Note 18 for additional information on
contingent consideration.
In January 2017, the Company acquired two solar PV projects currently under construction as well as associated
construction loan agreements with a bank for use in providing non-recourse financing for these acquired solar PV projects
currently under construction. The Company paid $2,409 to acquire the assets under construction, and assumed $5,635 of
associated non-recourse financing.
A summary of the cumulative consideration paid and the allocation of the purchase price of all of the acquisitions in each
respective year is as follows:
Accounts receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Prepaid expenses and other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Property and equipment and energy assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Intangibles . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Goodwill . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accounts payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accrued Exp. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred Revenue . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Purchase price . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Total, net of cash received. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Debt assumed . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Total fair value of consideration . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
2019
2018
2017
232 $
2
315
500
337
30
1
61
1,294 $
1,294 $
— $
1,294 $
1,015 $
12
—
680
2,845
67
—
—
4,619 $
4,619 $
— $
4,619 $
—
256
7,788
—
—
—
—
—
8,044
8,044
5,635
2,409
71
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
The results of the acquired assets since the dates of the acquisitions have been as presented in the accompanying
consolidated statements of income, consolidated statements of comprehensive income and consolidated statements of cash
flows.
For the year ended December 31, 2019, the Company had an additional measurement period adjustment of $628 related to
a 2018 acquisition which was recorded as a reduction to goodwill and included a $398 reduction in the holdback contingency
discussed further in Notes 5 and 15.
For the year ended December 31, 2019, in order to expand its portfolio of energy assets, the Company acquired nine solar
projects from two separate developers and is under definitive agreement to acquire ten additional solar projects. For the year
ended December 31, 2018, the Company acquired twelve solar projects from two separate developers and at December 31,
2018 was under definitive agreement to acquire six additional solar projects, three of which were subsequently acquired in
2019, and one of which was amended and will no longer be acquired.
The Company has concluded that in accordance with ASC 805, Business Combinations, these acquisitions in 2019 and
2018 did not constitute a business as the assets acquired in each case could be considered a single asset or group of similar
assets that made up substantially all of the fair market value of the acquisitions. See Note 7 for additional disclosures on these
asset acquisitions.
5. GOODWILL AND INTANGIBLE ASSETS
The changes in the carrying value of goodwill attributable to each reportable segment are as follows:
U.S. Regions
U.S. Federal
Canada
Other
Total
Balance, December 31, 2017 . . . . . . . . . . . . . . . . . . .
Goodwill acquired during the year . . . . . . . . . . . . . .
Currency effects . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Balance, December 31, 2018 . . . . . . . . . . . . . . . . . . .
Goodwill acquired during the year . . . . . . . . . . . . . .
Re-measurement adjustments . . . . . . . . . . . . . . . . . .
Currency effects . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Balance, December 31, 2019 . . . . . . . . . . . . . . . . . . .
Accumulated Goodwill Impairment Balance,
December 31, 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . $
Accumulated Goodwill Impairment Balance,
December 31, 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . $
24,759
1,611
—
26,370
337
(2)
—
26,705
3,375
1,234
—
4,609
—
(628)
—
3,981
3,494
—
(277)
3,217
—
—
152
3,369
24,507
—
(371)
24,136
—
—
223
56,135
2,845
(648)
58,332
337
(630)
375
24,359
58,414
— $
— $
(1,016) $
— $
(1,016)
— $
— $
(1,016) $
— $
(1,016)
In accordance with ASC 350, goodwill was tested for impairment as of December 31, 2019, 2018 and 2017 at the reporting
unit level under the income approach which uses, in part, a discounted cash flow method and a peer-based guideline method,
and a risk-adjusted weighted average cost of capital. No impairment was recorded in the December 31, 2019, 2018 or 2017
assessments. Based on the Company’s goodwill impairment assessment, all of its reporting units with goodwill had estimated
fair values as of December 31, 2019 and 2018 that exceeded their carrying values by at least 15% and 20%, respectively.
During the course of the valuation analysis it was determined that although the fair value of the Company’s Federal reporting
unit exceeded the carrying amount of this reporting unit, the carrying value of the reporting unit was negative as of December
31, 2019. The Federal reporting unit had goodwill of $3,981 as of December 31, 2019.
The gross carrying amount and accumulated amortization of intangible assets are as follows:
72 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
As of December 31,
2019
2018
Gross Carrying Amount
Customer contracts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Customer relationships. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Non-compete agreements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Technology . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Trade names . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accumulated Amortization
Customer contracts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Customer relationships. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Non-compete agreements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Technology . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Trade names . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
7,904
$
12,749
3,037
2,732
544
26,966
7,844
11,236
3,037
2,704
531
25,352
Intangible assets, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
1,614
$
7,818
12,082
3,013
2,710
541
26,164
7,668
10,302
3,013
2,651
526
24,160
2,004
Amortization expense related to customer contracts is included in cost of revenues in the consolidated statements of
income. Amortization expense related to customer relationships, non-compete agreements, technology and trade names is
included in selling, general and administrative expenses in the consolidated statements of income.
Customer contracts are amortized ratably over the period of the acquired customer contracts ranging in periods from
approximately one to eight years. All other intangible assets are amortized over periods ranging from approximately four to
fifteen years, as defined by the nature of the respective intangible asset.
Separable intangible assets that are not deemed to have indefinite lives are amortized over their useful lives. The Company
annually assesses whether a change in the life over which the Company’s assets are amortized is necessary or more frequently if
events or circumstances warrant. No changes to useful lives were made during the years ended December 31, 2019, 2018 and
2017.
Amortization expense for the years ended December 31, 2019, 2018 and 2017 is as follows:
Customer contracts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Customer relationships. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Non-compete agreements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Technology . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Trade names . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total intangible amortization expense . . . . . . . . . . . . . . . . . . . . . . . . . . . $
2019
Year Ended December 31,
2018
2017
90
806
1
12
—
909
$
$
30
973
3
47
4
1,057
$
$
31
1,244
42
128
6
1,451
73 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Amortization expense for the intangible assets related to customer contracts for the next five succeeding fiscal years is
immaterial. Amortization expense for the intangible assets related to customer relationships, non-compete agreements,
technology and trade names for the next five succeeding fiscal years is as follows:
2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Thereafter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Estimated Amortization
Included in Selling,
General and
Administrative Expenses
628
318
140
129
127
212
1,554
$
6. PROPERTY AND EQUIPMENT
Property and equipment consists of the following:
December 31,
2019
2018
Furniture and office equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Computer equipment and software costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Leasehold improvements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Automobiles . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Land . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Property and equipment, gross . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Less - accumulated depreciation. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Property and equipment, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
6,108
27,380
4,062
1,995
2,991
42,536
(32,432)
10,104
$
$
6,118
23,781
3,990
1,373
1,454
36,716
(29,731)
6,985
Depreciation expense on property and equipment for the years ended December 31, 2019, 2018 and 2017 was $2,987,
$2,167 and $2,394, respectively, and is included in selling, general and administrative expenses in the accompanying
consolidated statements of income.
74 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
7. ENERGY ASSETS
Energy assets consist of the following:
Energy assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Less - accumulated depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Energy assets, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
767,331
(187,870)
579,461
$
$
619,707
(159,756)
459,951
December 31,
2019
2018
Included in energy assets are financing lease assets and accumulated depreciation of financing lease assets. Financing
lease assets consist of the following:
Financing lease assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Less - accumulated depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Financing lease assets, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
December 31,
2019
2018
42,402
(6,268)
36,134
$
$
42,402
(4,139)
38,263
Depreciation and amortization expense on the above energy assets, net of deferred grant amortization, for the years ended
December 31, 2019, 2018 and 2017 was $35,543, $27,305 and $21,648, respectively, and is included in cost of revenues in the
accompanying consolidated statements of income. Included in these depreciation and amortization expense totals are
depreciation and amortization expense on financing lease assets of $2,129, $2,090, and $1,305 for the years ended
December 31, 2019, 2018 and 2017, respectively.
The Company capitalizes interest costs relating to construction financing during the period of construction. Capitalized
interest is included in energy assets, net in the Company’s consolidated balance sheets. Capitalized interest is amortized to cost
of revenues in the Company’s consolidated statements of income on a straight line basis over the useful life of the associated
energy asset. There was $2,966 and $3,817 of interest capitalized for the twelve months ended December 31, 2019 and 2018,
respectively.
As of December 31, 2019 and 2018, there are three ESPC asset projects which are included within energy assets, net on the
Company’s consolidated balance sheets. The Company controls and operates the assets as well as obtains financing during the
construction period of the assets. As the Company has an obligation to the customer for performance of the asset, the Company
records a liability associated with these energy assets, although, the customer is responsible for payments to the lender based on
the energy asset’s production. As of December 31, 2019 and 2018, the liabilities recognized in association with these assets
were $10,243 and $9,863, respectively, of which $827 and $354, respectively, has been classified as the current portion and is
included in accrued expenses and other current liabilities and the remainder is included in other liabilities in the accompanying
consolidated balance sheets.
For the year ended December 31, 2019, in order to expand its portfolio of energy assets, the Company acquired nine energy
projects, which did not constitute businesses under the new guidance. The Company acquired and closed on nine solar projects
from two developers for a total purchase price of $8,519. The purchase price included deferred consideration of $6,059,
included in accrued expenses and other current liabilities on the accompanying consolidated balance sheets, will be paid upon
final completion of the respective projects throughout 2020. As of December 31, 2019, the Company has paid $2,460 to the
developers of the projects. The Company also has a definitive agreement to purchase an additional ten solar projects from a
developer for a total purchase price of $13,902, of which, the Company has paid $366 to the developers of the projects.
For the year ended December 31, 2018, in order to expand its portfolio of energy assets, the Company acquired and closed
on twelve solar projects from two developers for a total purchase price of $72,921. The purchase price included deferred
consideration of $5,437 that will be paid upon final completion of the respective projects and throughout 2019. As of
December 31, 2018, the Company has paid $62,116 to the developers of the projects. As of December 31, 2019, deferred
purchase price consideration of $1,178, included in accrued expenses and other current liabilities on the accompanying
consolidated balance sheets, remains outstanding on the projects previously closed in 2018.
As of December 31, 2019, the Company had $852 in ARO assets recorded in project assets, net of accumulated
depreciation, and $941 in ARO liabilities recorded in accrued expenses and other current liabilities and other liabilities. During
75 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
the year end December 31, 2019, the Company recorded $45 of depreciation expense related to the ARO assets and $44 in
accretion expense to the ARO liability, which is reflected in the accretion of ARO and contingent consideration on the
consolidated statements of cash flows. As of December 31, 2018, the Company had $897 in ARO assets recorded in project
assets, net of accumulated depreciation, and $897 in ARO liabilities recorded in accrued expenses and other current liabilities
and other liabilities. During the year end December 31, 2018, the Company recorded $0 of depreciation expense related to the
ARO assets and $0 in accretion expense to the ARO liability. The Company’s current ARO liabilities relate to the removal of
equipment and pipelines at certain renewable gas projects and obligations related to the decommissioning of certain solar
facilities.
76
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
8. LEASES
On January 1, 2019, the Company adopted Topic 842, using the modified retrospective approach. The Company elected the
package of practical expedients available in the standard and as a result, did not reassess the lease classification of existing contracts
or leases or the initial direct costs associated with existing leases. The Company has also elected the practical expedient to not
separate lease components and non-lease components and will account for the leases as a single lease component for all classes
of leases.
As a result of the adoption of Topic 842, the Company recognized an increase in lease ROU assets of $31,639, current portions
of operating lease ROU liabilities of $5,084 and an increase to long-term portions of operating lease liabilities of $28,480, as of
January 1, 2019. There was no net impact to the consolidated statements of income or retained earnings for the adoption of Topic
842. No impairment was recognized on the ROU asset upon adoption. The adoption adjustments for the Company’s outstanding
operating and financing leases are detailed as follows:
As of January 1, 2019
As Reported
842 Adjustment
Adjusted
Balances
Operating Leases:
Operating lease assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Current portions of operating lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term portions of operating lease liabilities . . . . . . . . . . . . . . . . . . . . . . .
Total operating lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Weighted-average remaining lease term . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Weighted-average discount rate. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Financing Leases:
Energy assets, net. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Current portions of financing lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term financing lease liabilities, less current portions and net of
deferred financing fees. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total financing lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Weighted-average remaining lease term . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Weighted-average discount rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
— $
31,639
$
—
—
5,084
28,480
— $
33,564
$
38,263
$
— $
4,956
28,407
33,363
$
—
—
— $
31,639
5,084
28,480
33,564
10 years
6.0%
38,263
4,956
28,407
33,363
18 years
11.7%
The Company enters into a variety of operating lease agreements through the normal course of its business including certain
administrative offices. The leases are long-term, non-concealable real estate lease agreements, expiring at various dates through
fiscal 2028. The agreements generally provide for fixed minimum rental payments and the payment of utilities, real estate taxes,
insurance and repairs. The Company also leases certain land parcels related to our energy projects, expiring at various dates through
fiscal 2045. The office and land leases make up a significant portion of the Company’s operating lease activity. Many of these
leases have one or more renewal options that allow the Company, at it’s discretion, to renew the lease for six months to seven
years. Only renewal options that the Company believed were likely to be exercised were included in our lease calculations. Many
land leases include minimum lease payments that increase when the related project becomes operational. In these cases, the
commercial operation date was estimated by the Company and used to calculate the estimated minimum lease payments. Rent and
related expenses for the years ended December 31, 2019, 2018 and 2017 was $8,179, $6,463 and $6,362, respectively.
The Company also enters into leases for IT equipment and service agreements, automobiles, and other leases related to our
construction projects such as equipment, mobile trailers and other temporary structures. The Company utilizes the portfolio approach
for this class of lease. These leases are either short-term in nature or immaterial.
A portion of the Company’s real estate leases are generally subject to annual changes in the Consumer Price Index (“CPI”).
The Company utilized each lease’s minimum lease payments to calculate the lease balances upon transition. The subsequent
77 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
increases in rent based on changes in CPI were excluded and will be excluded for future leases from the calculation of the lease
balances, but will be recorded to the consolidated statement of income as part of our operating lease costs.
The Company has elected the practical expedient to not separate lease and non-lease components for existing leases for real
estate and land leases. The Company has historical leases under ASC 840, Leases, which may have lease and non-lease components.
Upon adoption of Topic 842, the Company has elected to continue to account for these historical leases as a single component, as
permitted by Topic 842. As of January 1, 2019, as it relates to all prospective leases, the Company will allocate consideration to
lease and non-lease components based on pricing information in the respective lease agreement, or, if this information is not
available, the Company will make a good faith estimate based on the available pricing information at the time of the lease agreement.
The discount rate was calculated using an incremental borrowing rate based on financing rates on secured comparable notes
with comparable terms and a synthetic credit rating calculated by a third party. The Company elected to apply the discount rate
using the remaining lease term at the date of adoption.
The Company has a number of leases that are classified as financing leases, which relate to transactions that are considered
sale-leasebacks under ASC 840. See the sale-leaseback section below for additional information on the Company’s financing
leases.
Supplemental balance sheet information related to leases at December 31, 2019 is as follows:
Operating Leases:
Operating lease assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Current operating lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term portions of operating lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total operating lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Weighted-average remaining lease term . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Weighted-average discount rate. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Financing Leases:
Energy assets, net. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Current portions of financing lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term financing lease liabilities, less current portions and net of deferred financing fees . . . . . . . .
Total financing lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Weighted-average remaining lease term . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Weighted-average discount rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
The costs related to our leases are as follows:
December 31, 2019
32,791
5,802
29,101
34,903
11 years
6.3%
36,134
4,997
23,500
28,497
17 years
11.8%
Year ended December 31,
2019
Operating Lease:
Operating lease costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
Financing Lease:
Amortization expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest on lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
7,460
2,129
3,630
Total lease costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
13,219
78
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
The Company’s estimated minimum future lease obligations under our leases are as follows:
Year ended December 31,
2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Thereafter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total minimum lease payments. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Less: interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Present value of lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Operating Leases
Financing Leases
7,768
6,340
5,775
4,486
3,668
21,220
49,257
14,354
34,903
$
$
$
8,078
6,775
5,173
3,686
2,585
24,215
50,512
22,015
28,497
Sale-Leaseback
During the first quarter of 2015, the Company entered into an agreement with an investor which gives the Company the
option to sell and contemporaneously lease back solar PV projects. This agreement expired on June 30, 2018. Additionally, the
Company sold and contemporaneously leased back one solar PV project to another investor, not a party to the master lease
agreement, under a new agreement during the year ended December 31, 2017. During August 2018, the Company entered into
an agreement with an investor which gives the Company the option to sell and contemporaneously lease back solar PV projects
through August 2019 up to a maximum funding amount of $100,000. During the year ended December 31, 2018, the Company
sold and contemporaneously leased back two solar PV projects. See below for a summary of solar PV project sales by fiscal
year:
Year Ended
Year-ended December 31,
2017. . . . . . . . . . . . . . . . . .
Year-ended December 31,
2018. . . . . . . . . . . . . . . . . .
# Solar PV
Projects
Sold
(actual #’s)
Sale Price
Deferred
Gain
Recorded
Deferred
Loss
Recorded
Financing
Lease
Asset/
Liability
Recorded
Initial
Lease
Term
(years)
13
$ 51,204
$ 4,625
$ 1,204
$ 22,934
10-20
2
$ 5,145
$
574
$
— $
2,625
20
Minimum
Lease
Payment
Maximum
Lease
Payment
$
$
4
3
$
$
510
144
During the year ended December 31, 2019, the Company amended the August 2018 agreement with the investor to extend
the end date of the agreement to November 24, 2019. During the year ended December 31, 2019, the Company sold three
projects and in return received $13.7 million. In accordance with Topic 842, Leases, the 2019 transactions were accounted for
as failed sales as the Company retains control of the underlying assets. The Company recorded the proceeds received from the
transactions as long term financing facilities with interest rate ranging from 0% to 0.28%, as a result of tax credits which were
transferred to the counterparty. See Note 9 for additional information on these finance facilities. As of December 31, 2019,
approximately $81 million remained available under the lending commitment.
In January 2020, the Company amended the August 2018 agreement with the investor to extend the end date of the
agreement to November 24, 2020 and increase the maximum funding amount up to $150 million.
79 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
A summary of amounts related to sale leasebacks in the Company’s consolidated balance sheets is as follows:
Financing lease assets, net. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Deferred loss, short-term, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred loss, long-term, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total deferred loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Financing lease liabilities, short-term . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Financing lease liabilities, long-term . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total financing lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Deferred gain, short-term, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred gain, long-term, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total deferred gain. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
December 31,
2019
December 31,
2018
36,134
115
1,801
1,916
4,997
23,500
28,497
345
5,463
5,808
$
$
$
$
38,263
115
1,917
2,032
4,956
28,407
33,363
345
5,808
6,153
Upon adoption of Topic 842, the Company elected to take the practical expedient and will not reassess lease classifications
at adoption. Accordingly, these sales-leasebacks will remain under the previous guidance.
80 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
9. LONG-TERM DEBT
Long-term debt comprised the following:
Commencement
Date
Maturity Date
Acceleration
Clause(2)
June 2024
June 2020
June 2031
June 2028
June 2024
March 2021
February 2021
Senior secured credit facility, interest at
varying rates monthly in arrears . . . . . . . . . . June 2015
Variable rate term loan payable in semi-
annual installments . . . . . . . . . . . . . . . . . . . . January 2006
Variable rate term loan payable in semi-
annual installments . . . . . . . . . . . . . . . . . . . . January 2006
Term loan payable in quarterly installments . March 2011
Term loan payable in monthly installments. . October 2011
Variable rate term loan payable in quarterly
installments . . . . . . . . . . . . . . . . . . . . . . . . . . October 2012
Variable rate term loan payable in quarterly
installments . . . . . . . . . . . . . . . . . . . . . . . . . . September 2015 March 2023
Term loan payable in quarterly installments . August 2016
Term loan payable in quarterly installments . March 2017
Term loan payable in monthly installments. . April 2017
Term loan payable in quarterly installments . April 2017
Variable rate term loan payable in quarterly
installments . . . . . . . . . . . . . . . . . . . . . . . . . . June 2017
Variable rate term loan payable in quarterly
installments . . . . . . . . . . . . . . . . . . . . . . . . . . February 2018 August 2022
Term loan payable in quarterly installments . June 2018
Variable rate term loan payable in semi-
annual installments . . . . . . . . . . . . . . . . . . . . June 2018
Variable rate term loan payable in monthly/
quarterly installments . . . . . . . . . . . . . . . . . . October 2018
Long term finance liability in semi-annual
installments (3) . . . . . . . . . . . . . . . . . . . . . . . . July 2019
Long term finance liability in semi-annual
installments (3) . . . . . . . . . . . . . . . . . . . . . . . . November 2019 November 2039
Term loan payable in quarterly installments . December 2019 December 2021
Financing leases(1) . . . . . . . . . . . . . . . . . . . . .
December 2038
December 2027
February 2034
October 2029
March 2028
April 2027
June 2033
July 2039
NA
Yes
Yes
Yes
NA
NA
NA
NA
NA
NA
NA
NA
Yes
Yes
Yes
Yes
NA
NA
Yes
Less - current maturities . . . . . . . . . . . . . . . .
Less - deferred financing fees . . . . . . . . . . . .
Long-term debt . . . . . . . . . . . . . . . . . . . . . . .
Rate as of
December
31,
Balance as of December
31,
2019
2019
2018
4.270% $112,216
$ 43,074
4.158%
625
936
3.908%
7.250%
6.110%
6,609
831
3,649
7,426
1,464
3,843
5.408% 28,217
30,674
4.408% 15,976
17,208
4.950%
5.000%
3,769
3,521
4.500% 22,553
5.610%
2,706
3,925
3,945
22,081
2,735
4.358% 11,740
12,915
9.408% 15,645
5.150% 28,583
21,475
30,069
3.958%
9,003
9,668
4.600%
9,092
9,072
0.280%
3,841
—%
8,794
6.500% 27,226
—
—
—
28,497
343,093
69,969
6,943
$266,181
33,363
253,873
26,890
7,821
$219,162
(1)Financing leases do not include approximately $22,015 in future interest payments
(2)These agreements have acceleration causes that, in the event of default, as defined, the payee has the option to accelerate
payment terms and make due the remaining principal and the required interest balance according to the agreement
(3) These agreements are sale-leaseback arrangements that provides for the sale of solar PV projects to a third party investor and
the simultaneous leaseback of the projects. In accordance with Topic 842, Leases, these transactions are accounted for as a
failed sale as the Company retains control of the underlying assets and as such, are classified as financing liabilities. The low
interest rates are the results of tax credits which were transferred to the coutnerparty.
81 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Aggregate maturities of long-term debt for the years ended December 31, are as follows:
2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Thereafter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Debt Discount. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
69,969
36,930
29,940
32,719
105,732
70,458
(2,655)
343,093
Senior Secured Credit Facility - Revolver and Term Loan
On June 28, 2019, we entered into a fourth amended and restated bank credit facility with three banks. The new credit
facility replaces and extends our existing credit facility, which was scheduled to expire on June 30, 2020. The amended
revolving credit and term loan facility mature on June 28, 2024, when all amounts will be due and payable in full. The
Company expects to use the new credit facility for general corporate purposes of the Company and its subsidiaries, including
permitted acquisitions, refinancing of existing indebtedness and working capital. The amendment increased the aggregate
amount of the revolving commitments from $85,000 to $115,000 through an extended June 28, 2024 maturity date, increased
the term loan from $40,000 to $65,000 to reduce the outstanding revolving loan balance by the same amount and extend the
maturity date from June 30, 2020 to June 28, 2024, and increased the total funded debt to EBITDA covenant ratio from a
maximum of 3.00 to 3.25. The total commitment under the amended credit facility (revolving credit, term loan and swing line)
is $185,000.
The credit facility consists of a $115,000 revolving credit facility and a $65,000 term loan. The revolving credit facility
may be increased by up to an additional $25,000 at the Company’s option if lenders are willing to provide such increased
commitments, subject to certain conditions. Up to $20,000 of the revolving credit facility may be borrowed in Canadian
dollars, Euros or pounds sterling. The Company is the sole borrower under the credit facility. The obligations under the credit
facility are guaranteed by certain of the Company’s direct and indirect wholly owned domestic subsidiaries and are secured by
a pledge of all of the Company’s and such subsidiary guarantors’ assets, other than the equity interests of certain subsidiaries
and assets held in non-core subsidiaries (as defined in the agreement). At December 31, 2019 and 2018, $62,563 and $41,500,
excluding debt discounts, was outstanding under the term loan, respectively. At December 31, 2019 and 2018, $50,073 and
$1,696, excluding debt discounts, was outstanding under the revolving credit facility, respectively. At December 31, 2019
funds of $29,144 were available for borrowing under the revolving credit facility. At December 31, 2019, the Company had
$13,090 in letters of credit outstanding.
The interest rate for borrowings under the credit facility is based on, at the Company’s option, either (1) a base rate equal
to a margin of 0.5% or 0.25%, depending on the Company’s ratio of total funded debt to EBITDA (as defined in the
agreement), over the highest of (a) the federal funds effective rate, plus 0.50% , (b) Bank of America’s prime rate and (c) a rate
based on the London interbank deposit rate (“LIBOR”) plus 1.50%, or (2) the one-, two- three- or six-month LIBOR plus a
margin of 2.00% or 1.75%, depending on the Company’s ratio of total funded debt to EBITDA, as defined. A commitment fee
of 0.375% is payable quarterly on the undrawn portion of the revolving credit facility. At December 31, 2019, the interest rate
for borrowings under the revolving credit facility was 4.70% and the weighted average interest rate for borrowings under the
term loan was 3.99%.
The revolving credit facility does not require amortization of principal. The term loan requires quarterly principal
payments of $1,219, with the balance due at maturity. All borrowings may be paid before maturity in whole or in part at the
Company’s option without penalty or premium, other than reimbursement of any breakage and deployment costs in the case of
LIBOR borrowings.
The credit facility limits the Company’s and its subsidiaries’ ability to, among other things: incur additional indebtedness;
incur liens or guarantee obligations; merge, liquidate or dispose of assets; make acquisitions or other investments; enter into
82 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
hedging agreements; pay dividends and make other distributions and engage in transactions with affiliates, except in the
ordinary course of business on an arms’ length basis.
Under the credit facility, the Company and its subsidiaries may not invest cash or property in, or loan to, the Company’s
non-core subsidiaries in aggregate amounts exceeding 49% of the Company’s consolidated stockholders’ equity. In addition,
under the credit facility, the Company and its core subsidiaries must maintain the following financial covenants:
a ratio of total funded debt to EBITDA, as defined, of less than 3.25 to 1.0 as of the end of each fiscal quarter ending
June 28, 2024 and thereafter; and
a debt service coverage ratio (as defined in the agreement) of at least 1.5 to 1.0.
•
•
Any failure to comply with the financial or other covenants of the credit facility would not only prevent the Company from
being able to borrow additional funds, but would constitute a default, permitting the lenders to, among other things, accelerate
the amounts outstanding, including all accrued interest and unpaid fees, under the credit facility, to terminate the credit facility,
and enforce liens against the collateral.
The credit facility also includes several other customary events of default, including a change in control of the Company,
permitting the lenders to accelerate the indebtedness, terminate the credit facility, and enforce liens against the collateral.
For purposes of the Company’s senior secured facility: EBITDA, as defined, excludes the results of certain renewable
energy projects that the Company owns and for which financing from others remains outstanding; total funded debt, as defined,
includes amounts outstanding under both the term loan and revolver portions of the senior secured credit facility plus other
indebtedness, but excludes non-recourse indebtedness of project company subsidiaries; and debt service, as defined, includes
principal and interest payments on the indebtedness included in total funded debt other than principal payments on the revolver
portion of the facility.
At December 31, 2019 funds of $29,144 are available for borrowing under the revolving credit facility.
July 2019 Long Term Finance Liability
In July 2019, the Company closed on one solar PV project under the Company’s master lease agreement, as discussed in
Note 8, with a twenty-year term. In accordance with Topic 842, Leases, this transaction was accounted for as a failed sale as the
Company retains control of the underlying assets. The proceeds received from the transaction were recorded by the Company
as a long term financing facility with an interest rate of 0.28%, as a result of tax credits which were transferred to the
counterparty. The principal and interest payments are due in semi annual installments and the long term finance facility matures
on July 16, 2039, with all remaining unpaid amounts outstanding under the agreement due at that time. At December 31, 2019,
$3,841 was outstanding under the long term finance liability.
November 2019 Long Term Finance Liability
In November 2019, the Company closed on two solar PV projects under the Company’s master lease agreement, as
discussed in Note 8, with a twenty-year term. In accordance with Topic 842, Leases, this transaction was accounted for as a
failed sale as the Company retains control of the underlying assets. The proceeds received from the transaction were recorded
by the Company as a long term financing facility with an interest rate of 0.00%, as a result of tax credits which were transferred
to the counterparty. The principal and interest payments are due in semi annual installments and the long term finance facility
matures on November 8, 2039, with all remaining unpaid amounts outstanding under the agreement due at that time. At
December 31, 2019, $8,794 was outstanding under the long term finance liability.
December 2019 Term Loan
In December 2019, the Company entered into a loan agreement at a fixed rate of 6.5% for gross proceeds of $27,473, for
use in providing non-recourse financing for purchase of solar PV modules. Principal and interest amounts are due in quarterly
installments beginning in March 2020. The term loan matures on December 31, 2021. At December 31, 2019, $26,970 was
outstanding under the term loan, net of debt discounts and deferred financing fees.
83 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
10. INCOME TAXES
The components of income before income taxes are as follows:
Domestic. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Foreign . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Income before (benefit) provision for income taxes . . . . . . . . . . . . . . . . $
34,700
1,853
36,553
$
$
46,542
(4,152)
42,390
$
$
29,792
(1,075)
28,717
The components of the (benefit) provision for income taxes are as follows:
2019
Year Ended December 31,
2018
2017
Current:
Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
State. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Foreign . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred:
Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
State. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Foreign . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
$
2019
Year Ended December 31,
2018
2017
109
$
474
(1)
582
(4,794)
202
262
(4,330) $
(3,748) $
(1,888) $
1,176
30
(682)
2,662
2,530
303
5,495
4,813
$
$
(1,055)
671
161
(223)
(6,683)
1,853
262
(4,568)
(4,791)
The Company’s deferred tax assets and liabilities result primarily from temporary differences between financial reporting
and tax recognition of depreciation, energy efficiency and NOL carryforwards.
84 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Deferred tax assets and liabilities consist of the following:
Deferred tax assets:
Compensation accruals. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Reserves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net operating losses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest rate swaps . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Energy efficiency . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest limitation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred revenue . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Gross deferred income tax assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Valuation allowance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total deferred income tax assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Deferred tax liabilities:
Depreciation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Deferred effect of derivative liability and ASU 2016-09 adoption . . . . . . . . . . . . . . . . . . .
Canadian capital cost, allowance and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
United Kingdom goodwill amortization. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Outside basis difference . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total deferred income tax liabilities. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred income tax liabilities, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
December 31,
2019
2018
$
1,745
2,739
9,398
14,355
1,604
35,939
5,148
1,635
72,563
(8,583)
63,980
$
(51,579) $
(328)
(2,919)
(781)
(8,488)
(64,095)
(115) $
3,489
2,940
127
10,010
666
28,911
3,292
1,943
51,378
(7,931)
43,447
(37,107)
(475)
(1,974)
(755)
(7,488)
(47,799)
(4,352)
The Company recorded a valuation allowance in the amount of $8,583 and $7,931 as of December 31, 2019 and 2018,
respectively, related to the following items: 1) The Company recorded a valuation allowance on a deferred tax asset relating to
interest rate swaps in the amount of $122 and $184 as of December 31, 2019 and 2018, respectively. The deferred tax asset
represents a future capital loss which can only be recognized for income tax purposes to the extent of capital gain
income. Although the Company anticipates sufficient future taxable income, it is more likely than not that it will not be of the
appropriate character to allow for the recognition of the future capital loss. 2) As of December 31, 2019 and 2018, the
Company recorded a valuation allowance on a deferred tax asset relating to a foreign net operating loss in the amount of $8,169
and $7,500, respectively. It is more likely than not that the Company will not generate sufficient taxable income at the foreign
subsidiary level to utilize the net operating loss. 3) The Company recorded a valuation allowance on a deferred tax asset
relating to a state net operating loss of $292 and $247 at one of its subsidiaries as of December 31, 2019 and 2018, respectively.
It is more likely than not that the Company will not generate sufficient taxable income at the subsidiary level to utilize the net
operating loss.
The provision for income taxes is based on the various rates set by federal and local authorities and is affected by
permanent and temporary differences between financial accounting and tax reporting requirements.
The principal reasons for the difference between the statutory rate and the estimated annual effective rate for 2019 related
to the Company’s recognizing a tax benefit of approximately $29.7 million associated with energy related credits and
deductions available under the U.S. Tax Code for 2019 as well as a deduction available under Section 179D of the Tax Code for
2019 and 2018. In December 2019, the Code Section 179D Commercial Buildings Energy Efficiency Tax Deduction was
retroactively extended for 2018 and 2019, and through the end of 2020. Because of the timing of the extension the impact of
the 2018 Section 179D deduction was not reflected in the 2018 tax provision but was instead reflected in 2019.
85 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
The following is a reconciliation of the effective tax rates:
Income before (benefit) provision for income taxes . . . . . . . . . . . . . . . . $
Federal statutory tax expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
State income taxes, net of federal benefit . . . . . . . . . . . . . . . . . . . . . . . .
Net state impact of deferred rate change . . . . . . . . . . . . . . . . . . . . . . . . .
Non deductible expenses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Impact of reserve for uncertain tax positions . . . . . . . . . . . . . . . . . . . . . .
Stock-based compensation expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Energy efficiency preferences . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Foreign items and rate differential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Redeemable non-controlling interests . . . . . . . . . . . . . . . . . . . . . . . . . . .
Tax rate change. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Valuation allowance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Miscellaneous. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
Effective tax rate:
Federal statutory rate expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
State income taxes, net of federal benefit . . . . . . . . . . . . . . . . . . . . . . . .
Net state impact of deferred rate change . . . . . . . . . . . . . . . . . . . . . . . . .
Non deductible expenses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Impact of reserve for uncertain tax positions . . . . . . . . . . . . . . . . . . . . . .
Stock-based compensation expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Energy efficiency preferences . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Foreign items and rate differential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Redeemable non-controlling interests . . . . . . . . . . . . . . . . . . . . . . . . . . .
Tax rate change. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Valuation allowance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Miscellaneous. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2019
36,553
7,676
2,140
(53)
150
(925)
(169)
(12,699)
56
1,101
—
205
(1,230)
(3,748)
$
$
$
$
Year Ended December 31,
2018
42,390
8,902
3,071
174
982
879
(441)
(8,636)
(41)
70
—
641
(788)
4,813
$
$
21.0 %
5.9 %
(0.1)%
0.4 %
(2.5)%
(0.5)%
(34.7)%
0.2 %
3.0 %
— %
0.6 %
(3.6)%
(10.3)%
21.0 %
7.2 %
0.4 %
2.3 %
2.1 %
(1.0)%
(20.4)%
(0.1)%
0.2 %
— %
1.5 %
(1.8)%
11.4 %
2017
28,717
10,048
1,584
327
1,473
42
116
(6,416)
139
1,579
(13,948)
424
(159)
(4,791)
35.0 %
5.5 %
1.1 %
5.1 %
0.1 %
0.4 %
(22.3)%
0.5 %
5.5 %
(48.6)%
1.5 %
(0.5)%
(16.7)%
A reconciliation of the beginning and ending balances of the total amounts of gross unrecognized tax benefits is as follows:
Year Ended December 31,
2018
2019
Balance, beginning of year. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Additions for current year tax positions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Additions for prior year tax positions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Settlements paid to tax authorities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Reductions of prior year tax positions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Balance, end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
1,600
—
—
—
(1,200)
400
$
$
600
300
900
—
(200)
1,600
At December 31, 2019 and 2018, the Company had approximately $400 and $1,600, respectively, of total gross
unrecognized tax benefits.
Of the total gross unrecognized tax benefits as of December 31, 2019 and 2018, $80 and $705, respectively, (both net of
the federal benefit on state amounts) represent the amount of unrecognized tax benefits that, if recognized, would favorably
affect the effective income tax rate in any future periods.
86 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
At December 31, 2019 the Company had a federal net operating loss carryforwards of approximately $34,090 which has an
indefinite life, state net operating loss carryforwards of approximately $45,260, which will expire from 2018 through 2034 and
an interest deduction carryforward of approximately $19,659 which has an indefinite life. At December 31, 2019 the Company
had Canadian net operating loss carryforwards of approximately $25,939, which will expire for tax years 2018 through 2028.
The Company does not accrue U.S. tax for foreign earnings that it considers to be permanently reinvested outside the
United States. Consequently, the Company has not provided any withholding tax on the unremitted earnings of its foreign
subsidiaries. As of December 31, 2019, the amount of earnings for which no repatriation tax has been provided is estimated to
be $0.
At December 31, 2019 the company had a federal tax credit carryforward of approximately $35,024 which will expire at
various times through 2039.
The tax years 2015 through 2019 remain open to examination by major taxing jurisdictions. The Company accounts for
interest and penalties related to uncertain tax positions as part of its provision for federal and state income taxes. The (decrease)
increase included in tax expense for the years end December 31, 2019, 2018 and 2017 was $19, $(50) and $60, respectively.
11. INVESTMENT FUNDS
In each of September 2015, June 2017, June 2018, October 2018, and December 2019 the Company formed an investment
fund with third party investors which granted the applicable investor ownership interests in the net assets of certain of the
Company’s renewable energy project subsidiaries. The Company currently has five such investment funds each with a different
third party investor.
The Company consolidates the investment funds, and all inter-company balances and transactions between the Company
and the investment funds are eliminated in its consolidated financial statements. The Company determined that the investment
funds meet the definition of a VIE. The Company uses a qualitative approach in assessing the consolidation requirement for
VIEs that focuses on determining whether the Company has the power to direct the activities of the VIE that most significantly
affect the VIE’s economic performance and whether the Company has the obligation to absorb losses or the right to receive
benefits that could potentially be significant to the VIE.
The Company has considered the provisions within the contractual arrangements that grant it power to manage and make
decisions that affect the operation of these VIEs, including determining the solar energy systems and associated long term
customer contracts to be sold or contributed to the VIEs, and installation, operation and maintenance of the solar energy
systems. The Company considers that the rights granted to the other investors under the contractual arrangements are more
protective in nature rather than participating rights. As such, the Company has determined it is the primary beneficiary of the
VIEs for all periods presented. The Company evaluates its relationships with VIEs on an ongoing basis to ensure that it
continues to be the primary beneficiary.
Under the related agreements, cash distributions of income and other receipts by the funds, net of agreed-upon expenses
and estimated expenses, tax benefits and detriments of income and loss, and tax benefits of tax credits, are assigned to the
funds’ investor and Company’s subsidiaries as specified in contractual arrangements. Certain of these arrangements have call
and put options to acquire the investor’s equity interest as specified in the contractual agreements. See Note 12 for additional
information on the call and put options.
87
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
A summary of amounts related to the investment funds in the Company’s consolidated balance sheets for the years ending
December 31, 2019 and 2018 is as follows:
2019(1)
2018(1)
Cash . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Restricted cash. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accounts receivable. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Costs and estimated earnings in excess of billings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Prepaid expenses and other current assets. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Property and equipment, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Energy assets, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Operating lease asset . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accounts payable. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accrued liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Current lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Current portions of long-term . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term debt, net of deferred financing costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other long-term liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4,666 $
586
532
1,125
108
1,266
142,456
6,511
1,662
2,006
2,203
102
2,252
24,654
6,180
1,171
1,255
156
374
498
190
—
122,641
—
1,613
234
4,146
—
1,712
26,461
—
2,131
(1)The amounts in the above table are reflected in parenthetical references on the Company’s consolidated balance sheets. See
the Company’s consolidated balance sheets for additional information.
Other Variable Interest Entities
The Company executes certain contracts jointly with third parties through various forms of joint ventures. Although the
joint ventures own and hold the contracts with the clients, the services required by the contracts are typically performed by the
Company and the Company’s joint venture partners, or by other subcontractors under subcontracting agreements with the joint
ventures. Many of these joint ventures are formed for a specific project. The assets of the Company’s joint ventures generally
consist almost entirely of cash and land, and the liabilities of our joint ventures generally consist almost entirely of amounts due
to the joint venture partners.
The Company follows guidance on the consolidation of VIEs that requires companies to utilize a qualitative approach to
determine whether it is the primary beneficiary of a VIE. The process for identifying the primary beneficiary of a VIE requires
consideration of the factors that indicate a party has the power to direct the activities that most significantly impact the joint
ventures economic performance, including powers granted to the joint ventures program manager, powers contained in the joint
venture governing board and, to a certain extent, a company's economic interest in the joint venture. The Company analyzes its
joint ventures and classifies them as either:
• a VIE that must be consolidated because the Company is the primary beneficiary or the joint venture is not a VIE and the
Company holds the majority voting interest with no significant participative rights available to the other partners; or
• a VIE that does not require consolidation and is treated as an equity method investment because the Company is not the
primary beneficiary or the joint venture is not a VIE and the Company does not hold the majority voting interest.
Many of the joint ventures are deemed to be VIEs because they lack sufficient equity to finance the activities of the joint
venture.
In January 2019, the Company entered into a joint venture with one other party to co-own an entity whose purpose is
owning and leasing a parcel of land and attached structures to third-party entities. The joint venture has no employees and is
controlled by the board of directors made up of representatives from both companies. Prior to January 2019, the Company had
determined it was the primary beneficiary of the VIE and fully consolidated the entity. Upon the formation of the joint venture,
the Company determined it was no longer the primary beneficiary, based on the assessment of considerations referenced above,
and deconsolidated the VIE and recorded the Company’s investment in the joint venture as an equity method investment. With
the deconsolidation of the VIE and the recognition of the equity method investment the Company recognized a gain of $2,160
88
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
in operating income and recorded an equity method investment of $1,361 in other assets. In addition, the Company has loaned
the joint venture $1,506 and made an initial contribution at its formation in exchange for 50% of the shares in the joint venture.
Unconsolidated joint ventures are accounted for under the equity method. For those joint ventures, the Company's
investment balances for the joint venture are included in other assets on the consolidated balance sheets and the Company’s pro
rata share of net income or loss is included in operating income. The Company’s investments in equity method joint ventures on
the consolidated balance sheets as of December 31, 2019 and 2018 was a net asset of $1,292 and $0, respectively. During the
years ended December 31, 2019 and 2018, the Company recognized expense of $183 and $0, respectively, from equity method
joint ventures.
12. NON-CONTROLLING INTERESTS AND EQUITY
Redeemable Non-controlling Interest
The Company’s wholly owned subsidiary with a membership interest in the investment fund formed in the third quarter of
2015 has the right, beginning on the fifth anniversary of the final funding of the variable rate construction and term loans due
2023 and extending for six months, to elect to require the non-controlling interest holder to sell all of its membership units to
the Company’s wholly owned subsidiary, a call option. The Company’s investment fund, which was formed in the third quarter
of 2015, also includes a right, beginning on the sixth anniversary of the final funding and extending for one year, for the non-
controlling interest holder to elect to require the Company’s wholly owned subsidiary to purchase all of its membership
interests in the fund, a put option.
The Company’s wholly owned subsidiary with a membership interest in the investment fund formed in the second quarter
of 2017 has the right, beginning on the fifth anniversary of the final funding of the non-controlling interest holder and extending
for six months, to elect to require the non-controlling interest holder to sell all of its membership units to the Company’s wholly
owned subsidiary, a call option. The Company’s investment fund formed in the second quarter of 2017 also includes a right,
beginning on the sixth anniversary of the final funding and extending for one year, for the non-controlling interest holder to
elect to require the Company’s wholly owned subsidiary to purchase all of its membership interests in the fund, a put option.
The Company’s wholly owned subsidiary with a membership interest in the investment fund formed in the second quarter
of 2018 has the right, beginning on the fifth anniversary of the investment fund’s final project being placed into service and
extending for six months, to elect to require the non-controlling interest holder to sell all of its membership units to the
Company’s wholly owned subsidiary, a call option. The Company’s investment fund formed in the second quarter of 2018 also
includes a right, upon the expiration of the call option and extending for six months, for the non-controlling interest holder to
elect to require the Company’s wholly owned subsidiary to purchase all of its membership interests in the fund, a put option.
The Company’s wholly owned subsidiary with a membership interest in the investment fund formed in the fourth quarter of
2018 has the right, beginning on the fifth anniversary on the last projects placed in-service date and extending for six months, to
elect to require the non-controlling interest holder to sell all of its membership units to the Company’s wholly owned
subsidiary, a call option. The Company’s investment fund formed in the fourth quarter of 2018 also includes a right, upon the
expiration of the call option and extending for six months, for the non-controlling interest partner to elect to require the
Company’s wholly owned subsidiary to purchase all of its membership interests in the fund, a put option.
The Company’s wholly owned subsidiary with a membership interest in the investment fund formed in the fourth quarter of
2019 has the right, beginning on the fifth anniversary on the last projects placed in-service date and extending for six months, to
elect to require the non-controlling interest holder to sell all of its membership units to the Company’s wholly owned
subsidiary, a call option. The Company’s investment fund formed in the fourth quarter of 2019 also includes a right, beginning
six months after the fifth anniversary of the final funding and extending for one year, for the non-controlling interest partner to
elect to require the Company’s wholly owned subsidiary to purchase all of its membership interests in the fund, a put option.
The purchase price for two of the investment funds investors’ interests under the call options is equal to the fair market
value of such interest at the time the option is exercised. The purchase price for two of the investment funds investor’s interests
under the call options is equal to the greater of (i) the fair market value of such interests at the time the option is exercised or
(ii) 7% of the investors’ contributed capital balance at the time the option is exercisable. The purchase price for the remaining
investment fund investor’s interests under the call options is equal to the greater of (i) the fair market value of such interests at
the time the option is exercised or (ii) 5% of the investors’ contributed capital balance at the time the option is exercisable.The
89
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
call options are exercisable beginning on the date that specified conditions are met for each respective fund. None of the call
options are expected to become exercisable prior to 2021.
The purchase price for two of the funds investors’ interests in the investment funds under the put options is the lessor of
fair market value at the time the option is exercised and a specified amount, ranging from $659 - $917. The purchase price for
the two remaining funds investors’ interest in the investment funds under the put options is the sum of (i) the fair market value
at the time the option is exercised, and (ii) the closing costs incurred by the investor in connection with the exercise of the put
option. The purchase price for the remaining fund investors’ interest in the investment funds under the put options is the lessor
of fair market value at the time the option is exercised and the sum of (i) 5% of the investors’ contributed capital balance at the
time the option is exercisable, and (ii) the fair market value of any unpaid tax law change losses incurred by the investor in
connection with the exercise of the put option. The put options for the investment funds are exercisable beginning on the date
that specified conditions are met for each respective fund. The put options are not expected to become exercisable prior to 2022.
Because the put options represents redemption features that are not solely within the control of the Company, the non-
controlling interests in these funds are presented outside of permanent equity. Redeemable non-controlling interests are reported
using the greater of their carrying value at each reporting date (which is impacted by attribution under the HLBV method) or
their estimated redemption value in each reporting period. At both December 31, 2019 and 2018, redeemable non-controlling
interests were reported in the accompanying consolidated balance sheets at their carrying value of $31,616 and $14,719,
respectively, as the carrying value at each reporting period was greater than the estimated redemption value.
13. STOCK INCENTIVE PLAN
Common and Preferred Stock
The Company has authorized 500,000 shares of Class A common stock, par value $0.0001 per share, 144,000 shares of
Class B common stock, par value $0.0001 per share, and 5,000 shares of Preferred Stock, par value $0.0001 per share. The
rights of the holders of the Company’s Class A common stock and Class B common stock are identical, except with respect to
voting and conversion. Each share of the Company’s Class A common stock is entitled to one vote per share and is not
convertible into any other shares of the Company’s capital stock. Each share of the Company’s Class B common stock is
entitled to five votes per share, is convertible at any time into one share of Class A common stock at the option of the holder of
such share and will automatically convert into one share of Class A common stock upon the occurrence of certain specified
events, including a transfer of such shares (other than to such holder’s family members, descendants or certain affiliated
persons or entities). The Company’s Board of Directors is authorized to fix the rights and terms for any series of preferred stock
without additional shareholder approval.
In 2000, the Company’s Board of Directors approved the Company’s 2000 Stock Incentive Plan (the “2000 Plan”) and
between 2000 and 2010 authorized the Company to reserve a total of 28,500 shares of its then authorized common stock, par
value $0.0001 per share (”Common Stock”) for issuance under the 2000 Plan. The 2000 Plan provided for the issuance of
restricted stock grants, incentive stock options and nonqualified stock options. The Company will grant no further stock options
or restricted awards under the 2000 Plan.
The Company’s 2010 Stock Incentive Plan (the “2010 Plan”), was adopted by the Company’s Board of Directors in May
2010 and approved by its stockholders in June 2010. The 2010 Plan provides for the grant of incentive stock options, non-
statutory stock options, performance-based stock options, restricted stock awards and other stock-based awards. Upon its
effectiveness, 10,000 shares of the Company’s Class A common stock were reserved for issuance under the 2010 Plan. As of
December 31, 2019, the Company had granted options to purchase 5,217 shares of Class A common stock under the 2010 Plan.
The Company’s 2017 Employee Stock Purchase Plan ("ESPP") permits eligible employees to purchase up to an aggregate
of 200 shares of the Company’s Class A common stock. This plan commenced December 1, 2017 and was most recently
amended on August 2018. The ESPP allows participants to purchase shares of common stock at a 5% discount from the fair
market value of the stock as determined on specific dates at six-month intervals. During the years ended December 31, 2019
and 2018, the Company issued 49 and 51 shares, respectively, under the ESPP. As of December 31, 2019, the amount that had
been withheld from employees for future purchases under the ESPP is $0.1 million. As of December 31, 2018, the amount that
had been withheld from employees for future purchases under the ESPP was immaterial.
90 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Stock Option Grants
The Company has granted stock options to certain employees and directors, including its principal and controlling
stockholder, under the 2000 Plan. The Company has also granted stock options to certain employees and directors under the
2010 Plan. At December 31, 2019, 5,717 shares were available for grant under the 2010 Plan.
The following table summarizes the collective activity under the 2000 Plan and the 2010 Plan:
Outstanding at December 31, 2016 . . . . . . . . . . . . . . . . . . . . . . . . .
Granted(1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Exercised. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Forfeited . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Expired . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Outstanding at December 31, 2017 . . . . . . . . . . . . . . . . . . . . . . . . .
Granted(1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Exercised. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Forfeited . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Expired . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Outstanding at December 31, 2018 . . . . . . . . . . . . . . . . . . . . . . . . .
Granted(1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Exercised. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Forfeited . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Expired . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Outstanding at December 31, 2019 . . . . . . . . . . . . . . . . . . . . . . . . .
Options exercisable at December 31, 2019 . . . . . . . . . . . . . . . . . . .
Expected to vest at December 31, 2019 . . . . . . . . . . . . . . . . . . . . . .
(1) Grants are related to the 2010 Plan.
Number of
Options
3,971
390
(401)
(41)
(85)
3,834
518
(909)
(87)
(51)
3,305
1,330
(916)
(210)
(4)
3,505
1,528
1,977
Weighted-
Average
Exercise Price
7.300
6.061
4.935
6.421
10.157
7.367
10.878
7.367
4.726
9.146
8.050
14.026
7.362
8.070
9.904
10.524
8.757
11.889
$
$
$
Weighted-
Average
Remaining
Contractual
Term
Aggregate
Intrinsic Value
6.60
4.01
8.76
$
$
$
24,455
13,356
11,098
The aggregate intrinsic value of stock options exercised during the years ended December 31, 2019, 2018 and 2017 was
$7,154, $5,588 and $808, respectively.
During the year ended December 31, 2019, a total of 916 shares were issued upon the exercise of options under the 2000
and 2010 Plan at an average price of 7.362 per share. Cash received from option exercises under all stock-based payment
arrangements, net, for the years ended December 31, 2019, 2018 and 2017 was $6,742, $6,696 and $1,977, respectively.
Stock options issued under our 2000 Plan generally expire if not exercised within ten years after the grant date. Under the
terms of our 2010 stock incentive plan, all options expire if not exercised within ten years after the grant date. During 2011, the
Company began awarding options which typically vest over a five year period on an annual ratable basis. From time to time,
the Company awards options providing for vesting over three years, with one-third vesting on each of the first three
anniversaries of the grant date. During the year ending December 31, 2019, the Company granted 1,000 common stock options
to certain employees and directors under its 2010 Stock Incentive Plan, which have a contractual life of ten years and vest
based upon the achievement of specific performance goals over a three years. If the employee ceases to be employed by the
Company for any reason before vested options have been exercised, the employee has 90 days to exercise options that have
vested as of the date of such employee’s termination or they are forfeited.
During August and September 2019, the Company’s Chief Executive Officer (“CEO”), who is also a significant
shareholder of the Company, exercised a nonqualified option to purchase 600 shares of the Company’s Class A common stock.
Due to an administrative oversight, in November 2019, the Company paid the required withholding taxes of $2,292 to the
91 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Internal Revenue Service on the compensation element resulting from such exercise without a corresponding withholding from
the CEO. Accordingly, the Company recorded a reimbursement due from the CEO as of December 31, 2019 of $2,292, which
has been included in prepaid expenses and other current assets in the accompanying balance sheet. In January 2020, the
Company received payment in full from the CEO.
The Company uses the Black-Scholes option pricing model to determine the weighted-average fair value of options
granted. The Company will recognize the compensation cost of stock-based awards on a straight-line basis over the vesting
period of the award.
The determination of the fair value of stock-based payment awards utilizing the Black-Scholes model is affected by the
stock price and a number of assumptions, including expected volatility, expected life, risk-free interest rate and expected
dividends. The following table sets forth the significant assumptions used in the model during 2019, 2018 and 2017:
Expected dividend yield . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Risk-free interest rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Expected volatility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Expected life. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Year Ended December 31,
2019
—%
1.60%-2.39%
43%-44%
6.5 years
2018
—%
2.71%-3.00%
43%-45%
6.5 years
2017
—%
1.96%-2.36%
46%
6.5 years
The Company will continue to use judgment in evaluating the expected term and volatility related to the stock-based
compensation on a prospective basis, and incorporating these factors into the Black-Scholes pricing model. The Company
records forfeitures as they occur. Higher volatility and longer expected lives result in an increase to stock-based compensation
expense determined at the date of grant.
The weighted-average fair value of stock options granted during the years ended December 31, 2019, 2018 and 2017,
under the Black-Scholes option pricing model was $6.33, $5.20 and $2.93, respectively, per share. For the years ended
December 31, 2019, 2018 and 2017, the Company recorded stock-based compensation expense of approximately $1,620,
$1,258, and $1,293, respectively, in connection with stock-based payment awards and including expense in connection with the
ESPP. The compensation expense is categorized as a portion of selling, general and administrative expenses in the
accompanying consolidated statements of income. As of December 31, 2019, there was approximately $9,486 of unrecognized
compensation expense related to non-vested stock option awards that is expected to be recognized over a weighted-average
period of 2.7 years.
14. EMPLOYEE BENEFITS
The Company has salary reduction/profit sharing plans under the provisions of Section 401(k) of the Internal Revenue
Code. The plans cover all employees who have completed the minimum service requirement, as defined by the plans. The plans
require the Company to contribute 100% of the first six percent of base compensation that a participant contributes to the plans.
Matching contributions made by the Company were $5,452, $4,957, and $3,832 for the years ended December 31, 2019, 2018
and 2017, respectively.
The Company has a Group Personal Pension Plan (GPPP) for employees in the U.K., established in 2016, whereby eligible
employees may contribute a portion of their compensation, subject to their age and other limitations established by HM
Revenue & Customs. The plan requires the Company to contribute 100% of the first six percent of base compensation that a
participant contributes to the plans. Matching contributions made by the Company were $190, $161, and $344 for the years
ended December 31, 2019, 2018 and 2017, respectively.
The Company has a Registered Retirement Savings Plan (RRSP) for employees in Canada, whereby eligible employees
may contribute a portion of their compensation. The plan requires the Company to contribute 100% of the first six percent of
base compensation that a participant contributes to the plans. Matching contributions made by the Company were $356, $351,
and $774 for the years ended December 31, 2019, 2018 and 2017, respectively.
15. COMMITMENTS AND CONTINGENCIES
The Company from time to time issues letters of credit and performance bonds, with their third-party lenders, to provide
collateral.
92
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
The Company has future lease commitments which do not yet meet the criteria of a ROU asset or ROU liability as of
December 31, 2019, for certain business offices. These commitments total $721 as of December 31, 2019 and relate to
payments through 2026.
Legal Proceedings
The Company also is involved in a variety of claims and other legal proceedings generally incidental to its normal business
activities. While the outcome of any of these proceedings cannot be accurately predicted, the Company does not believe the
ultimate resolution of any of these existing matters would have a material adverse effect on its financial condition or results of
operations.
Commitments as a Result of Acquisitions
In May 2018, the Company completed an acquisition which provided for a $425 cash consideration holdback contingent
upon the Company collecting certain acquired receivables, which was subsequently reduced to $0 as of December 31, 2019 in
connection with the measurement period adjustment discussed in Note 5.
In August 2018, the Company completed an acquisition which provided for a revenue earn-out contingent upon the
acquired business meeting certain cumulative revenue targets over the next five years. The Company evaluated financial
forecasts of the acquired business and concluded that the fair value of this earn-out was approximately $555 upon acquisition.
The fair value was $599 as of December 31, 2018 and $678 as of December 31, 2019, and is recorded in the other liabilities on
the consolidated balance sheets. The contingent consideration will be paid yearly, commencing in 2021, if any of the
cumulative revenue targets are achieved and the fair value of the earn-out will be periodically re-evaluated and adjustments will
be recorded as needed. See Notes 4 and 18 for additional information.
In November 2018, the Company completed an asset acquisition of certain lease options, which provided for a payout if
the lease option is exercised and if certain financial metrics are achieved. The Company evaluated the the acquired lease
options and concluded that the fair-value of this contingent liability was approximately $363 as of December 31, 2018, which
was subsequently increased to $378 as of December 31, 2019 and is recorded in accrued expenses and other current liabilities
and other liabilities on the consolidated balance sheets. Payments will be made when milestones are achieved. The contingent
liability will be periodically re-evaluated and adjustments will be recorded as needed. See Note 18 for additional information.
16. GEOGRAPHIC INFORMATION
The Company attributes revenues to customers based on the location of the customer. Information as to the Company’s
operations in different geographical areas is as follows:
Long-lived assets:
United States . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Canada . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total long-lived assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
564,047
24,684
834
589,565
$
$
443,385
22,107
1,445
466,937
December 31,
2019
2018
Revenues:
United States . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Canada . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
815,405
35,031
16,497
866,933
$
$
734,748
36,728
15,662
787,138
$
$
665,793
42,186
9,173
717,152
2019
Year Ended December 31,
2018
2017
93 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
17. OTHER EXPENSES, NET
The components of other expenses, net, are as follows:
Gain on derivatives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Interest expense, net of interest income. . . . . . . . . . . . . . . . . . . . . . . . . .
Amortization of deferred financing fees, net . . . . . . . . . . . . . . . . . . . . . .
Foreign currency transaction (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . .
Other expenses, net. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
(1,068) $
13,841
2,229
59
15,061
$
(121) $
13,132
1,894
1,804
16,709
$
(271)
8,086
1,350
(1,294)
7,871
2019
Year Ended December 31,
2018
2017
Estimated amortization expense for existing deferred financing fees for the next five succeeding fiscal years is as follows:
2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Estimated
Amortization
1,484
1,083
881
674
532
18. FAIR VALUE MEASUREMENT
The Company recognizes its financial assets and liabilities at fair value on a recurring basis (at least annually). Fair value
is defined as the price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most
advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date.
Three levels of inputs that may be used to measure fair value are as follows:
Level 1: Inputs are based upon unadjusted quoted prices for identical instruments traded in active markets.
Level 2: Inputs are based upon quoted prices for similar instruments in active markets, quoted prices for identical or
similar instruments in markets that are not active, and model based valuation techniques for which all significant assumptions
are observable in the market or can be corroborated by observable market data for substantially the full term of the assets or
liabilities.
Level 3: Inputs are generally unobservable and typically reflect management’s estimates of assumptions that market
participants would use in pricing the asset or liability. The fair values are therefore determined using model-based techniques
that include option pricing models, discounted cash flow models, and similar techniques.
The following table presents the input level used to determine the fair values of the Company’s financial instruments
measured at fair value on a recurring basis:
Level
2019
2018
Fair Value as of December 31,
Assets:
Interest rate swap instruments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Commodity swap instruments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Liabilities:
Interest rate swap instruments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Commodity swap instruments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest make-whole provisions . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Contingent consideration liabilities . . . . . . . . . . . . . . . . . . . . . . . . . .
Total liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2
2
2
2
2
3
$
$
$
$
15
198
213
6,236
—
918
678
7,832
$
$
$
733
33
766
3,187
70
1,808
599
5,664
94 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
The fair value of the Company’s interest rate swaps was determined using cash flow analysis on the expected cash flow of
the contract in combination with observable market-based inputs, including interest rate curves and implied volatilities. As part
of this valuation, the Company considered the credit ratings of the counterparties to the interest rate swaps to determine if a
credit risk adjustment was required.
The fair value of the Company’s commodity swaps was determined using a cash flow analysis on the expected cash flow
of the contract in combination with observable forward price inputs obtained from a third-party pricing source. As part of this
valuation, the Company considered the credit ratings of the counterparties to the commodity swaps to determine if a credit risk
adjustment was required.
The fair value of the Company’s make-whole provisions were determined by comparing them against the rates of similar
debt instruments under similar terms without a make-whole provision obtained from various highly rated third-party pricing
sources.
The fair value of the Company’s contingent consideration liabilities were determined by evaluating the acquired asset’s
future financial forecasts and evaluating which, if any, of the cumulative revenue targets, financial metrics and/or milestones
are likely to be met. The Company has classified contingent consideration related to certain acquisitions within Level 3 of the
fair value hierarchy because the fair value is derived using significant unobservable inputs, which include discount rates and
probability-weighted cash flows. The Company determined the fair value of its contingent consideration obligations based on a
probability-weighted income approach derived from financial performance estimates and probability assessments of the
attainment of certain targets. The Company establishes discount rates to be utilized in its valuation models based on the cost to
borrow that would be required by a market participant for similar instruments. In determining the probability of attaining
certain technical, financial and operation targets, the Company utilizes data regarding similar milestone events from our own
experience, while considering the inherent difficulties and uncertainties in developing a product. On a quarterly basis, the
Company reassesses the probability factors associated with the financial, operational and technical targets for its contingent
consideration obligations. Significant judgment is employed in determining the appropriateness of these assumptions as of the
acquisition date and for each subsequent period.
The key assumptions as of December 31, 2019, related to the contingent consideration from the acquisition of certain
assets of Chelsea Group Limited, used in the model include a discount rate of 18% for purposes of discounting the low and
base case scenarios associated with achievement of the financial based earn-out. The probabilities assigned to these scenarios
were 50% for both the low and base case scenarios. An increase or decrease in the probability of achievement of any scenario
could result in a significant increase or decrease to the estimated fair value of the contingent consideration liability.
The following table sets forth a summary of changes in fair value of contingent liabilities classified as Level 3 for the year
ended December 31, 2019 and 2018:
Year Ended
December 31, 2019
December 31, 2018
Contingent consideration liabilities balance at the beginning of year. $
Contingent consideration issued in connection with acquisitions .
Loss on change in fair value. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Contingent consideration liabilities balance at the end of year. . . . . . $
599 $
—
79
678 $
—
555
44
599
The fair value of financial instruments is determined by reference to observable market data and other valuation
techniques, as appropriate. The only category of financial instruments where the difference between fair value and recorded
book value is notable is long-term debt. At December 31, 2019 and 2018, the fair value of the Company’s long-term debt was
estimated using discounted cash flows analysis, based on the Company’s current incremental borrowing rates for similar types
of borrowing arrangements which are considered to be level two inputs. There have been no transfers in or out of level two or
three for the years ended December 31, 2019 and 2018. Based on the analysis performed, the fair value and the carrying value
of the Company’s long-term debt, excluding financing leases, are as follows:
95
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
December 31, 2019
December 31, 2018
Fair Value
Carrying Value
Fair Value
Carrying Value
Long-term debt value (Level 2) . . . . . . . . . . . . . . . . . . . . $
309,377
$
307,508
$
211,823
$
212,687
The Company is also required periodically to measure certain other assets at fair value on a nonrecurring basis, including
long-lived assets, goodwill and other intangible assets. The Company determined the fair value used in its annual goodwill
impairment analysis with its own discounted cash flow analysis. The Company has determined the inputs used in such analysis
as Level 3 inputs. There were no assets recorded at fair value on a non-recurring basis at December 31, 2019 or 2018.
19. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES
At December 31, 2019 and 2018, the following table presents information about the fair value amounts of the Company’s
derivative instruments:
Derivatives as of December 31,
2019
2018
Balance Sheet
Location
Fair Value
Balance Sheet
Location
Fair Value
Derivatives Designated as Hedging Instruments:
Interest rate swap contracts . . . . . . . . . . . . . . . . . . Other assets
Interest rate swap contracts . . . . . . . . . . . . . . . . . . Other liabilities
Derivatives Not Designated as Hedging Instruments:
Interest rate swap contracts . . . . . . . . . . . . . . . . . . Other assets
Commodity swap contracts . . . . . . . . . . . . . . . . . . Other assets
Interest rate swap contracts . . . . . . . . . . . . . . . . . . Other liabilities
Commodity swap contracts . . . . . . . . . . . . . . . . . . Other liabilities
Interest make-whole provisions . . . . . . . . . . . . . . . Other liabilities
$
$
$
$
$
$
$
15 Other assets
6,210 Other liabilities
— Other assets
198 Other assets
26 Other liabilities
— Other liabilities
918 Other liabilities
$
$
$
$
$
$
$
703
3,187
30
33
—
70
1,808
All but three of the Company’s freestanding derivatives were designated as hedging instruments as of December 31, 2019
and all but four of the Company’s derivatives were designated as hedging instruments as of December 31, 2018.
The following tables present information about the effects of the Company’s derivative instruments on the consolidated
statements of income and consolidated statements of comprehensive income:
Location of (Gain)
Loss Recognized in Net
Income
Amount of (Gain) Loss Recognized in Net Income for
the Year Ended December 31,
2019
2018
2017
Derivatives Designated as Hedging Instruments:
Interest rate swap contracts . . . . . . . . . . . . . . . . . . . Other expenses, net
Derivatives Not Designated as Hedging Instruments:
Interest rate swap contracts . . . . . . . . . . . . . . . . . . . Other expenses, net
Commodity swap contracts . . . . . . . . . . . . . . . . . . . Other expenses, net
Interest make-whole provisions. . . . . . . . . . . . . . . . Other expenses, net
$
$
$
$
71
$
(196) $
(271)
56
$
(234) $
(890) $
(308) $
$
36
$
337
—
—
—
Derivatives Designated as Hedging Instruments:
Accumulated loss in AOCI at the beginning of the period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Cumulative impact from the adoption of ASU No. 2018-02 . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Unrealized loss recognized in AOCI . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Gain reclassified from AOCI to other expenses, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accumulated loss in AOCI at the end of the period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
(1,824)
(217)
(2,630)
(71)
(4,742)
Year Ended
December 31, 2019
96 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
In March 2010, the Company entered into a fourteen-year interest rate swap contract under which the Company agreed to
pay an amount equal to a specified fixed rate of interest times a notional amount, and to in turn receive an amount equal to a
specified variable rate of interest times the same notional principal amount. The swap covered an initial notional amount of
approximately $27,900 variable rate note at a fixed interest rate of 3.74% and expired in December 2024. This swap was designated
as a hedge in March 2013. During the second quarter of 2014, this swap was de-designated and re-designated as a hedge as a result
of a partial pay down of the associated hedged debt principal. As a result $566 was reclassified from accumulated other
comprehensive loss and recorded as a reduction to other expenses, net in the Company’s consolidated statements of income (loss)
during the second quarter of 2014. During the second quarter 2018, this swap was de-designated as a hedge as a result of the
expected pay down of the associated hedged debt principal. As a result, $34 was reclassified from accumulated other comprehensive
loss and recorded to other expenses, net in the Company’s consolidated statements of income during the second quarter 2018. In
the third quarter of 2018, the expected pay down of the hedged debt principal occurred and the balance of the related hedge was
written off. This resulted in a decrease of other liabilities of $252 in the Company’s consolidated balance sheets and a corresponding
decrease in other expenses, net in the Company’s consolidated statements of income.
In the third quarter of 2018, the Company adopted ASU 2017-12 Derivatives and Hedging (Topic 815), which resulted in an
increase to retained earnings of $432 and accumulated other comprehensive loss of $486 to remove the cumulative effect of
hedging ineffectiveness previously recognized in earnings, as of July 1, 2018, for contracts designated as hedging instruments that
were outstanding at the beginning of the third quarter 2018. Upon adoption of the ASU, the impact to reclassify the ineffectiveness
of the Company’s hedge instruments in connection with prior periods was recorded. Accordingly, the Company’s consolidated
statement of changes in redeemable non-controlling interests and stockholders’ equity for the years ended December 31, 2019 and
2018, reflect the adoption of ASU 2017-12.
The followings tables present a listing of all the Company’s active derivative instruments as of December 31, 2019:
Active Interest Rate Swap
Effective Date
Expiration Date
October 2029
June 2033
11-Year, 5.77% Fixed . . . . . . . . . . . . October 2018
15-Year, 5.24% Fixed. . . . . . . . . . . . June 2018
3-Year, 2.46% Fixed. . . . . . . . . . . . . March 2018
10-Year, 4.74% Fixed. . . . . . . . . . . . June 2017
15-Year, 3.26% Fixed. . . . . . . . . . . . February 2023
7-Year, 2.19% Fixed. . . . . . . . . . . . . February 2016
8-Year, 3.70% Fixed. . . . . . . . . . . . . March 2020
8-Year, 3.70% Fixed. . . . . . . . . . . . . March 2020
8-Year, 1.71% Fixed. . . . . . . . . . . . . October 2012
8-Year, 1.71% Fixed. . . . . . . . . . . . . October 2012
15-Year, 5.30% Fixed. . . . . . . . . . . . February 2006
15.5-Year, 5.40% Fixed . . . . . . . . . . September 2008 March 2024
March 2020
March 2020
June 2028
June 2028
December 2020
December 2027
December 2038
February 2023
February 2021
Initial Notional
Amount ($)
Status
$
9,200 Designated
10,000 Designated
17,100 Not Designated
14,100 Designated
14,084 Designated
20,746 Designated
14,643 Designated
10,734 Designated
9,665 Designated
7,085 Designated
3,256 Designated
13,081 Designated
Active Commodity Swap
Effective Date
1-Year, $2.68 MMBtu Fixed. . . . . . . May 2019
1-Year, $2.70 MMBtu Fixed. . . . . . . May 2020
Expiration
Date
April 2020
April 2021
Initial
Notional
Amount
(Volume)
Commodity
Measurement Status
437,004 MMBtus
Not Designated
435,810 MMBtus
Not Designated
97
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
Other Derivatives
Classification
Effective Date
Expiration Date
Fair Value ($)
Interest make-whole provisions . . . . Liability
June/August
2018
December 2038
$
918
20. BUSINESS SEGMENT INFORMATION
The Company reports results under ASC 280, Segment Reporting. The Company’s reportable segments for the year ended
December 31, 2019 are U.S. Regions, U.S. Federal, Canada and Non-Solar Distributed Generation (“Non-Solar DG”). The
Company’s U.S. Regions, U.S. Federal and Canada segments offer energy efficiency products and services which include the
design, engineering and installation of equipment and other measures to improve the efficiency and control the operation of a
facility’s energy infrastructure, renewable energy solutions and services which include the construction of small-scale plants
that the Company owns or develops for customers that produce electricity, gas, heat or cooling from renewable sources of
energy and O&M services. The Company’s Non-Solar DG segment sells electricity, processed renewable gas fuel, heat or
cooling, produced from renewable sources of energy, other than solar, and generated by small-scale plants that the Company
owns and O&M services for customer owned small-scale plants. The Company’s U.S. Regions segment also includes certain
small-scale solar grid-tie plants developed for customers. The “All Other” category offers enterprise energy management
services, consulting services and the sale of solar PV energy products and systems which we refer to as integrated-PV. These
segments do not include results of other activities, such as corporate operating expenses not specifically allocated to the
segments. Certain reportable segments are an aggregation of operating segments. For the years ended December 31, 2019,
2018 and 2017 unallocated corporate expenses were $34,156, $30,415 and $27,195, respectively.
For the years ended December 31, 2019, 2018 and 2017 more than 75% of the Company’s revenues have been derived
from federal, state, provincial or local government entities, including public housing authorities and public universities. The
U.S. federal government, which is considered a single customer for reporting purposes, constituted 33.2%, 31.3% and 32.0% of
the Company’s consolidated revenues for the years ended December 31, 2019, 2018 and 2017, respectively. Revenues from the
U.S. federal government are included in the Company’s U.S. Federal segment.
The reports of the Company’s chief operating decision maker do not include assets at the operating segment level.
98 AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
An analysis of the Company’s business segment information and reconciliation to the consolidated financial statements is
as follows:
U.S. Regions
U.S. Federal
Canada
Non-Solar DG
All Other
Total
Consolidated
2019
Revenues . . . . . . . . . . . . . . . . . . . . . $
Interest income. . . . . . . . . . . . . . . . .
Interest expense . . . . . . . . . . . . . . . .
Depreciation and intangible asset
amortization . . . . . . . . . . . . . . . . . . .
Unallocated corporate activity . . . . .
Income before taxes, excluding
unallocated corporate activity . . . . .
2018
Revenues . . . . . . . . . . . . . . . . . . . . .
Interest income. . . . . . . . . . . . . . . . .
Interest expense . . . . . . . . . . . . . . . .
Depreciation and intangible asset
amortization . . . . . . . . . . . . . . . . . . .
Unallocated corporate activity . . . . .
Income (loss) before taxes,
excluding unallocated corporate
activity . . . . . . . . . . . . . . . . . . . . . . .
2017
Revenues . . . . . . . . . . . . . . . . . . . . .
Interest income. . . . . . . . . . . . . . . . .
Interest expense . . . . . . . . . . . . . . . .
Depreciation and intangible asset
amortization . . . . . . . . . . . . . . . . . . .
Unallocated corporate activity . . . . .
Income before taxes, excluding
unallocated corporate activity . . . . .
365,060
$
287,426
$
37,910
$
84,683
$
91,854
$
866,933
166
5,858
9,934
—
208
831
3,427
—
15,925
40,553
334,344
246,309
9
6,188
5,578
—
126
1,045
2,772
—
—
691
1,386
—
1,771
38,982
—
1,917
1,155
—
82
5,242
21,359
—
3,813
82,655
147
6,172
18,101
—
68
—
1,603
—
8,647
84,848
—
22
1,542
—
524
12,622
37,709
(34,156)
70,709
787,138
282
15,344
29,148
(30,415)
20,543
36,332
(2,746)
13,412
5,264
72,805
290,196
229,146
2
2,672
2,974
—
44
1,056
2,623
—
13,865
29,261
43,803
1
1,927
1,178
—
1,751
79,220
83
3,389
15,259
—
8,115
74,787
717,152
—
38
1,881
—
2,920
130
9,082
23,915
(27,195)
55,912
Information as to the Company’s revenues by service and product lines is as follows:
Project. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Energy Assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
O&M . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Integrated-PV . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2019
Year Ended December 31,
2018
2017
611,064
$
545,053
$
506,550
98,042
66,709
47,953
43,165
95,776
65,236
41,349
39,724
69,241
60,574
38,796
41,991
Total Revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
866,933
$
787,138
$
717,152
99
AMERESCO, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(in thousands, except per share amounts)
21. QUARTERLY INFORMATION (Unaudited)
The following tables set forth selected unaudited consolidated statements of income data for each of the most recent eight
quarters ended December 31, 2019. Operating results for any quarter are not necessarily indicative of results for any future
period.
Three Months Ended,
March 31
June 30
September 30
December 31
2019
Revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Gross profit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Net income attributable to common shareholders . . . . . . . . . $
Net income per share attributable to common shareholders:
Basic. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Weighted average common shares outstanding:
Basic. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2018
Revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Gross profit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Net income attributable to common shareholders . . . . . . . . . $
150,112
32,632
4,147
0.09
0.09
46,293
47,654
167,410
35,473
6,988
Net income per share attributable to common shareholders:
Basic. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
0.15
0.15
Weighted average common shares outstanding:
Basic. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
45,373
45,994
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
198,183
43,139
9,216
0.20
0.19
46,387
47,681
196,982
42,776
8,702
0.19
0.19
45,470
46,406
$
$
$
$
$
$
$
$
$
$
212,026
44,693
8,870
0.19
0.19
46,555
47,693
205,375
46,162
10,701
0.23
0.23
45,854
46,944
306,612
47,654
22,203
0.47
0.46
47,101
48,061
217,371
49,201
11,593
0.25
0.24
46,114
47,327
100 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Shareholders of
Ameresco, Inc.
Opinions on the Financial Statements and Internal Control over Financial Reporting
We have audited the accompanying consolidated balance sheets of Ameresco, Inc. and Subsidiaries (the Company) as of December
31, 2019 and 2018 and the related consolidated statements of income, comprehensive income, changes in redeemable non-
controlling interest and stockholders’ equity, and cash flows for each of the years in the three-year period ended December 31,
2019, and the related notes (collectively, the financial statements). We also have audited the Company's internal control over
financial reporting as of December 31, 2019, based on the criteria established in Internal Control - Integrated Framework issued
by the Committee of Sponsoring Organizations of the Treadway Commission in 2013.
In our opinion, the 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 three years in the period
ended December 31, 2019 in conformity with accounting principles generally accepted in the United States of America. Also in
our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December
31, 2019, based on the criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring
Organizations of the Treadway Commission in 2013.
Basis for Opinion
The Company's management is responsible for these 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 Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the
Company's 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 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 financial statements included performing procedures to assess the risks of material misstatement of the 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 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 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.
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
101 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/ RSM US LLP
We have served as the Company's auditor since 2010.
Boston, Massachusetts
March 4, 2020
102 Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
None.
Item 9A. Controls and Procedures
Evaluation of Disclosure Controls and Procedures
Our management, with the participation of our principal executive officer and principal financial officer, evaluated the
effectiveness of our disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act,
as of the end of the period covered by this annual report, or the evaluation date. Disclosure controls and procedures are
designed to ensure that information required to be disclosed by a company in the reports that it files or submits under the
Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms.
Our management recognizes that any controls and procedures, no matter how well designed and operated, can provide only
reasonable assurance of achieving their objectives, and management necessarily applies its judgment in evaluating the cost-
benefit relationship of possible controls and procedures. Our management, after evaluating the effectiveness of our disclosure
controls and procedures as of the evaluation date, concluded that as of the evaluation date, our disclosure controls and
procedures were effective at the reasonable assurance level.
Management’s Annual Report on Internal Control over Financial Reporting
Our management, with the participation of our principal executive officer and principal financial officer, is responsible for
establishing and maintaining adequate internal control over our financial reporting as defined in Rules 13a-15(f) and 15d-15(f)
under the Exchange Act as a process designed by, or under the supervision of, a company’s principal executive and principal
financial officers and effected by our board of directors, management and other personnel to provide reasonable assurance
regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance
with GAAP. Our internal control over financial reporting includes those policies and procedures that:
•
•
•
pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect our transactions and
dispositions of our assets;
provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements
in accordance with GAAP, and that our receipts and expenditures are being made only in accordance with
authorizations of our management and directors; and
provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition
of our assets that could have a material effect on our financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements.
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.
Our management assessed the effectiveness of our internal control over financial reporting as of December 31, 2019. In
making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway
Commission (COSO) in Internal Control - Integrated Framework (2013).
Based on this assessment and those criteria, our management concluded that, as of December 31, 2019, our internal control
over financial reporting was effective.
The effectiveness of our internal control over financial reporting as of December 31, 2019 has been audited by RSM US
LLP, an independent registered public accounting firm, as stated in their report, which appears under Item 8.
Changes in Internal Control over Financial Reporting
There were no changes in our internal control over financial reporting, other than those stated above, during our most
recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over
financial reporting.
Item 9B. Other Information
None.
103 PART III
Item 10. Directors, Executive Officers and Corporate Governance
The information concerning our executive officers is set forth under the heading “Executive Officers” at the end of Item 1
in Part I of this report.
We have adopted a written code of business conduct and ethics that applies to our directors, officers and employees,
including our principal executive officer, principal financial officer, principal accounting officer or controller, and persons
performing similar functions. A copy of the code of business conduct and ethics is posted on the Investor Relations section of
our website, which is located at www.ameresco.com. In addition, we intend to post on our website all disclosures that are
required by law or applicable NYSE listing standards concerning any amendments to, or waivers from, any provision of the
code. We include our website address in this report only as an inactive textual reference and do not intend it to be an active link
to our website. None of the material on our website is part of this Annual Report on Form 10-K.
The response to the remainder of this item is incorporated by reference from the discussion responsive thereto in the
sections titled “Corporate Governance” and “Stock Ownership - Section 16(a) Beneficial Ownership Reporting Compliance”
contained in the definitive proxy statement for our 2020 annual meeting of stockholders.
Item 11. Executive Compensation
The response to this item is incorporated by reference from the discussion responsive thereto in the sections titled
“Executive Compensation and Related Information” and “Corporate Governance” contained in the definitive proxy statement
for our 2020 annual meeting of stockholders.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
Equity Compensation Plan Information
The following table provides information about the securities authorized for issuance under our equity compensation plans
as of December 31, 2019:
Equity Compensation Plan Information
(a)
(b)
Number of securities to be
issued upon exercise of
outstanding options,
warrants and rights
Weighted-average
exercise price of
outstanding options,
warrants and rights
(c)
Number of securities
remaining available for
future issuance under
equity compensation plans
(excluding securities
reflected in column (a))
3,505,000
$
—
3,505,000
$
10.524
—
10.524
5,785,049
—
5,785,049
Plan category
Equity compensation plans approved by security
holders(1)(2). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Equity compensation plans not approved by
security holders . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(1) Consists of our 2000 stock incentive plan and our 2010 stock incentive plan and our 2017 employee stock purchase
plan.
(2) Consists of 5,717,228 shares of our class A common stock remaining available for future issuance are under our 2010
stock incentive plan and 99,655 shares of our class A common stock remaining available for future issuance under our
2017 employee stock purchase plan, including shares subject to purchase during the current purchase period. In
addition to being available for future issuance upon exercise of options that may be granted after December 31, 2019,
shares under our 2010 stock incentive plan may instead be issued in the form of stock appreciation rights, restricted
stock, restricted stock units and other stock-based awards.
The response to the remainder of this item is incorporated by reference from the discussion responsive thereto in the section
titled “Stock Ownership” contained in the definitive proxy statement for our 2020 annual meeting of stockholders.
104 Item 13. Certain Relationships and Related Transactions, and Director Independence
The response to this item is incorporated by reference from the discussion responsive thereto in the sections titled “Certain
Relationships and Related Person Transactions” and “Corporate Governance” contained in the definitive proxy statement for
our 2020 annual meeting of stockholders.
Item 14. Principal Accountant Fees and Services
The response to this item is incorporated by reference from the discussion responsive thereto in the section titled
“Proposal 2 - Ratification of the Selection of our Independent Registered Public Accounting Firm” contained in the definitive
proxy statement for our 2020 annual meeting of stockholders.
Item 15. Exhibits and Financial Statement Schedules
(a)(1) Consolidated Financial Statements.
PART IV
The following consolidated financial statements of Ameresco, Inc. are filed in Item 8 of this Annual Report on Form 10-K:
Consolidated Balance Sheets as of December 31, 2019 and December 31, 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Statements of Income for the years ended December 31, 2019, December 31, 2018 and December 31,
2017. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Statements of Comprehensive Income for the years ended December 31, 2019, December 31, 2018
and December 31, 2017 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Statements of Changes in Redeemable Non-Controlling Interest and Stockholders’ Equity for the
years ended December 31, 2019, December 31, 2018 and December 31, 2017. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Statements of Cash Flows for the years ended December 31, 2019, December 31, 2018 and
December 31, 2017 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
47
49
49
50
51
Notes to Consolidated Financial Statements. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
53
Report of Independent Registered Public Accounting Firm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
101
(2) Financial Statement Schedules.
Schedules are omitted because they are not applicable, or are not required, or because the information is included in the
consolidated financial statements and notes thereto.
(3) Exhibits.
The exhibits filed or furnished with this report or that are incorporated herein by reference are set forth in the Exhibit Index
immediately preceding such exhibits, which Exhibit Index is incorporated herein by reference.
105 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.
SIGNATURE
Date: March 4, 2020
AMERESCO, INC.
By:
/s/ George P. Sakellaris
George P. Sakellaris
President and Chief Executive Officer
106 Pursuant to the requirements of the Securities Exchange Act of 1934, this Annual Report on Form 10-K has been signed
below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.
SIGNATURES
Signature
/s/ George P. Sakellaris
George P. Sakellaris
/s/ Spencer Doran Hole
Spencer Doran Hole
/s/ Mark Chiplock
Mark Chiplock
/s/ David J. Anderson
David J. Anderson
/s/ David J. Corrsin
David J. Corrsin
/s/ Douglas I. Foy
Douglas I. Foy
/s/ Thomas S. Murley
Thomas S. Murley
/s/ Nickolas Stavropoulos
Nickolas Stavropoulos
/s/ Jennifer L. Miller
Jennifer L. Miller
/s/ Joseph W. Sutton
Joseph W. Sutton
/s/ Frank V. Wisneski
Frank V. Wisneski
Title
Chairman of the Board of Directors,
President and Chief Executive Officer
(Principal Executive Officer)
Senior Vice President and Chief Financial
Officer
(Principal Financial Officer)
Vice President and Chief Accounting Officer
(Principal Accounting Officer)
Director
Director
Director
Director
Director
Director
Director
Director
Date
March 4, 2020
March 4, 2020
March 4, 2020
March 4, 2020
March 4, 2020
March 4, 2020
March 4, 2020
March 4, 2020
March 4, 2020
March 4, 2020
March 4, 2020
107 Exhibit Index
Exhibit
Number
3.1
3.2
4.1
4.16*
10.1.1
10.2.1+
10.2.2+
10.2.3+
10.3.1+
10.3.2+
10.3.3+
10.4.1+
10.4.2+
10.5.1+
Description
Amended and Restated Certificate of Incorporation of Ameresco, Inc. Filed as Exhibit 3.1 to our
Current Report on Form 8-K dated July 27, 2010 and filed with the Commission on July 30, 2010
(file no. 001-34811) and incorporated herein by reference.
Amended and Restated By-Laws of Ameresco, Inc. (as further amended May 22, 2014). Filed as
Exhibit 3.1 to our Quarterly Report on Form 10-Q for the fiscal quarter ended June 30, 2014 and
filed with the Commission on July 31, 2014 (file no. 011-34811) and incorporated herein by
reference. Filed as Exhibit 3.1 to our Registration Statement on Form S-1 (pre-effective
amendment no. 4; reg. no. 333-165821) and incorporated herein by reference.
Specimen Certificate evidencing shares of Class A common stock. Filed as Exhibit 4.1 to our
Registration Statement on Form S-1 (pre-effective amendment no. 4; reg. no. 333-165821) and
incorporated herein by reference.
Description of Ameresco, Inc. Securities Registered under Section 12 of the Exchange Act
Third Amended and Restated Credit and Security Agreement dated June 30, 2015 among
Ameresco, Inc., certain guarantors party thereto, certain lenders party thereto from time to time
and Bank of America, N.A. as Administrative Agent. Filed as Exhibit 10.1 to our Current Report
on Form 8-K dated June 30, 2015 and filed with the Commission on July 2, 2015 (file no.
001-34811) and incorporated herein by reference.
Ameresco, Inc. 2000 Stock Incentive Plan. Filed as Exhibit 10.6 to our Registration Statement on
Form S-1 (reg. no. 333-165821) and incorporated herein by reference.
Form of Incentive Stock Option Agreement granted under Ameresco, Inc. 2000 Stock Incentive
Plan. Filed as Exhibit 10.7 to our Registration Statement on Form S-1 (reg. no. 333-165821) and
incorporated herein by reference.
Form of Non-Qualified Stock Option Agreement granted under Ameresco, Inc. 2000 Stock
Incentive Plan. Filed as Exhibit 10.8 to our Registration Statement on Form S-1 (reg. no.
333-165821) and incorporated herein by reference.
Ameresco, Inc. 2010 Stock Incentive Plan. Filed as Exhibit 10.10 to our Registration Statement
on Form S-1 (pre-effective amendment no. 4; reg. no. 333-165821) and incorporated herein by
reference.
Form of Incentive Stock Option Agreement granted under Ameresco, Inc. 2010 Stock Incentive
Plan. Filed as Exhibit 10.11 to our Registration Statement on Form S-1 (pre-effective amendment
no. 4; reg. no. 333-165821) and incorporated herein by reference.
Form of Director Stock Option Agreement granted under Ameresco, Inc. 2010 Stock Incentive
Plan. Filed as Exhibit 10.12 to our Registration Statement on Form S-1 (pre-effective amendment
no. 4; reg. no. 333-165821) and incorporated herein by reference.
Form of Indemnification Agreement entered into between Ameresco, Inc. and each non-employee
director. Filed as Exhibit 10.6.1 to our Annual Report on Form 10-K for the fiscal year ended
December 31, 2010 and filed with the Commission on March 31, 2011 (file no. 001-34811) and
incorporated herein by reference.
Form of Indemnification Agreement entered into between Ameresco, Inc. and each employee
director. Filed as Exhibit 10.6.2 to our Annual Report on Form 10-K for the fiscal year ended
December 31, 2010 and filed with the Commission on March 31, 2011 (file no. 001-34811) and
incorporated herein by reference.
Ameresco, Inc. 2017 Employee Stock Purchase Plan, as amended. Filed as Exhibit 10.1 to our
Quarterly Report on Form 10-Q for the fiscal quarter ended June 30, 2018 and filed with the
Commission on August 8, 2018 (file no. 001-34811) and incorporated herein by reference.
108 Exhibit
Number
10.6.1+
10.7+
21.1*
23.1*
31.1*
31.2*
32.1**
101
Description
Ameresco, Inc. Executive Management Team Additional Annual Incentive Performance Program.
Filed as Exhibit 10.2 to our Quarterly Report on Form 10-Q for the fiscal quarter ended June 30,
2017 and filed with the Commission on August 9, 2017 (file no. 001-34811) and incorporated
herein by reference.
Agreement between the Ameresco, Inc. and John R. Granara, III, dated December 17, 2018. Filed
as Exhibit 10.1 to our Current Report on Form 8-k dated December 18, 2018 and filed with the
Commission on December 20, 2018 (file no. 001-34811) and incorporated herein by reference.
Subsidiaries of Ameresco, Inc.
Consent of RSM US LLP.
Principal Executive Officer Certification required by Rule 13a-14(a) or Rule 15d-14(a) of the
Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act
of 2002.
Principal Financial Officer Certification required by Rule 13a-14(a) or Rule 15d-14(a) of the
Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act
of 2002.
Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002.
The following consolidated financial statements from Ameresco, Inc.’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 Income, (iii)
Consolidated Statements of Comprehensive Income, (iv) Consolidated Statement of Changes in
Redeemable Non-Controlling Interests and Stockholders’ Equity, (v) Consolidated Statements of
Cash Flows, and (vi) Notes to Consolidated Financial Statements.
*
Filed herewith.
** Furnished herewith.
+
Identifies a management contract or compensatory plan or arrangement in which an executive officer or director
of Ameresco participates.
++ Confidential treatment requested as to certain portions, which portions have been omitted and filed separately with
the Securities and Exchange Commission.
109 DIRECTORS
EXECUTIVE OFFICERS
George P. Sakellaris
Chairman, President and Chief Executive Officer, Ameresco
George P. Sakellaris
Chairman, President and Chief Executive Officer
David J. Anderson
Executive Vice President, Ameresco
David J. Anderson
Executive Vice President
David J. Corrsin
Executive Vice President, General Counsel and Secretary, Ameresco
Michael T. Bakas
Executive Vice President, Distributed Energy Systems
Douglas I. Foy
President, Serrafix Corporation
Nicole A. Bulgarino
Executive Vice President and General Manager, Federal Solutions
Spencer Doran Hole
Senior Vice President and Chief Financial Officer, Ameresco
Mark A. Chiplock
Vice President and Chief Accounting Officer
Jennifer L. Miller
Chief Business Sustainability Officer (Retired), Sappi North America
David J. Corrsin
Executive Vice President, General Counsel and Secretary
Thomas S. Murley
Principal, Two Lights Energy Advisors LLC
Spencer Doran Hole
Senior Vice President and Chief Financial Officer
Nickolas Stavropoulos
President and Chief Operating Officer (Retired), Pacific Gas and
Electric Company
Louis P. Maltezos
Executive Vice President
SHAREHOLDER INFORMATION
Copies of all SEC filings, including our 10-K, are available
on our website under the Investor Relations section.
GENERAL INFORMATION
Ameresco Inc.
1-866-AMERESCO
info@ameresco.com
Joseph W. Sutton
Chief Executive Officer, Sutton Ventures Group
Frank V. Wisneski
Partner (Retired), Wellington Management Company
CORPORATE HEADQUARTERS
Ameresco Inc.
111 Speen Street
Suite 410
Framingham, MA 01701
508.661.2200
ameresco.com
STOCK LISTING
Our common stock is traded on the New York Stock
Exchange under the symbol AMRC.
Transfer Agent
American Stock Transfer and Trust
New York, NY
VISION
Energizing a sustainable world.
MISSION
Leading the quest to change the world as the trusted sustainability partner
creating valued, single-sourced, efficient energy solutions delivered with
passion, expertise, teamwork and a relentless focus on customer satisfaction.
VALUES
Ameresco’s values shape our culture and the way we conduct business. Our
values are aligned with CARING about our stakeholders and are instrumental
in guiding every aspect of our business.
2019
A N N U A L R E P O R T
Printed on recycled paper.
© 2020 Ameresco, Inc. Ameresco and the Ameresco logo, the orb symbol and the tagline
“Green. Clean. Sustainable.” are registered in the U.S. Patent and Trademark Office. All rights reserved.