Arga , I c.
ANNUAL
REPORT
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ABOUT US
SENIOR MANAGEMENT
Rainer H. Bosselmann
Chairman of the Board of Directors,
Chief Execu�ve Officer
David H. Watson
Senior Vice President, Chief Financial Officer,
Treasurer and Secretary
Richard H. Deily
Vice President, Corporate Controller
DIRECTORS
Rainer H. Bosselmann
Cynthia A. Flanders
Peter W. Getsinger
William F. Griffin
John R. Jeffrey
Mano S. Koilpillai
William F. Leimkuhler
W.G. Champion Mitchell
James W. Quinn
AUDITORS
Grant Thornton LLP
Arlington, Virginia
COUNSEL
Culhane Meadows PLLC
New York, New York
TRANSFER AGENT
New York, New York
Con�nental Stock Transfer & Trust Company
ANNUAL MEETING
The 2022 Annual Mee�ng of Argan, Inc. will be
held on June 21, 2022 at 11:00 a.m. at One Church
Street, Room 104, Rockville, Maryland 20850.
STOCKHOLDER INFORMATION
Our common stock is listed on the NYSE under the
symbol AGX.
Copies of the Annual Report on Form 10-K as filed
with the Securi�es and Exchange Commission are
available without charge to Stockholders of record
as of April 27, 2022 upon request at Corporate
Headquarters.
SUBSIDIARIES
Gemma Power Systems
www.gemmapower.com
The Roberts Company
www.robertscompany.com
Atlan�c Projects Company
www.atlan�cprojects.com
SMC Infrastructure Solu�ons
www.smcis.com
Transfer Agent
Front Cover: Guernsey Power Sta�on is an 1,875 MW natural gas-fired power plant that Gemma Power Systems is construc�ng in Guernsey
County, Ohio. Using state-of the art combined cycle technology and an air-cooling system for each power train, Guernsey Power Sta�on has
the capability to provide electricity to approximately one million homes. It is the largest, single-phase, gas-fired power plant construc�on
project in the United States.
Back Cover: A ground view of one of three air-cooled condensers at Guernsey Power Sta�on that u�lizes dry cooling technology to reduce
water usage by as much as 95% compared to a standard water-cooled power plant.
Inside Back Cover: Atlan�c Projects Company completed the mechanical installa�on of one of the world’s largest biomass boilers for the
Teesside (UK) Renewable Energy Plant in early 2021. TeesREP is a 299 MW power plant that will burn primarily wood pellets to generate
electricity for 600,000 homes.
One Church Street
One Church Street
Suite 201
Suite 201
Rockville, MD 20850
Rockville, MD 20850
301-315-0027
301-315-0027
fax 301-315-0064
fax 301-315-0064
www.arganinc.com
www.arganinc.com
May 4, 2022
Dear Fellow Stockholders:
The recent fiscal year ended January 31, 2022 was a year of operational and financial growth for
Argan compared to the prior year. We achieved 30% and 82% increases in our consolidated
revenues and EBITDA, respectively, with increases being generated by all of our businesses.
While part of this growth can be attributed to the waning unfavorable effects of the COVID-19
pandemic, we believe it has primarily been the confirmation of the effectiveness of our
conservative approach and our dedicated employees.
We reported consolidated revenues of $509 million for the year ended January 31, 2022. Our
performance reflected substantially the construction activities on the Guernsey Power Station as
the revenues earned on this project drove the revenues of the power services business segment
up. We accomplished these increases in revenues while improving our consolidated gross margin
percentage to 20% for the current year from about 16% last year. The gross margin percentages
for power industry services, industrial fabrication and field services and telecommunications
infrastructure services were 20%, 17% and 17% for the year ended January 31, 2022,
respectively.
We reported net income attributable to our stockholders of $38.2 million, or $2.40 per diluted
share, for the year ended January 31, 2022. Last year, we reported net income attributable to our
stockholders in the amount of $23.9 million, or $1.51 per dilutive share.
We had several new projects starts this year. Atlantic Projects Company was awarded the Kilroot
project to build a 2 X 330 MW gas-fired power plant in Northern Ireland. Continuing a pattern
established in the United States, the construction of this plant will contribute to the air quality of
the region by enabling the shutdown of a coal-fired power plant facility while at the same time
enhancing power reliability.
Gemma Power Systems commenced activities pursuant to the award of an EPC services contract
to construct the Maple Hill Solar facility, which we believe will be among the largest solar-
powered energy plants in Pennsylvania. We believe that this project is significant to the
renewable energy diversification of our power plant construction business as construction will
include the installation of over 235,000 photovoltaic modules sufficient to provide a 100 MW
power rating for this solar field. The revenues associated with this and other renewable energy
projects represented 13% of the revenues of the power industry service business for the current
year.
Looking forward, we are working hard to continue winning new projects to replace certain
revenues of our major projects expected to be completed before the end of calendar year 2022.
While it was difficult to see a few of our identified EPC project developments become
unsuccessful, we still believe there are a number of meaningful projects that will start this year
for each of our subsidiaries. Since year end, our business in Ireland already has received limited
notices to proceed with early activities related to the construction of two new gas-fired power
plant facilities near Dublin. Also, we continue to be pleased with the current execution on all of
our major projects despite the well-publicized global supply chain disruptions and current
inflationary challenges.
Delivering value to our customers and stockholders is our top priority. We are committed to a
disciplined capital allocation strategy that balances returning capital to our stockholders and
investing in our business and people. With this in mind, our Board of Directors recently
approved an increase in the Company's existing share repurchase program, from $25
million to $75 million. We were pleased to return over $36 million in value back to our
stockholders during the year ended January 31, 2022 through the stock repurchase and our
regular cash dividends programs.
Finally, we appreciate the loyalty of our stockholders and extend our best wishes to you, and to
all of our other stakeholders, for your safety and prosperity throughout the new year.
Sincerely,
Rainer H. Bosselmann
Chairman and Chief Executive Officer
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
UNITED STATES
Washington, D.C. 20549
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
FORM 10-K
☒ ANNUAL REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934.
☒ ANNUAL REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934.
For the Fiscal Year Ended January 31, 2022
or
For the Fiscal Year Ended January 31, 2022
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934.
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934.
For the transition period from to
or
For the transition period from to
Commission File Number 001-31756
Commission File Number 001-31756
Arga , I c.
ARGAN, INC.
ARGAN, INC.
(Exact Name of Registrant as Specified in its Charter)
(Exact Name of Registrant as Specified in its Charter)
Delaware
(State or Other Jurisdiction of Incorporation or Organization)
Delaware
(State or Other Jurisdiction of Incorporation or Organization)
One Church Street, Suite 201, Rockville, Maryland
(Address of Principal Executive Offices)
One Church Street, Suite 201, Rockville, Maryland
(Address of Principal Executive Offices)
13-1947195
(IRS Employer Identification No.)
13-1947195
(IRS Employer Identification No.)
20850
(Zip Code)
20850
(Zip Code)
(301) 315-0027
(Issuer’s Telephone Number, Including Area Code)
(301) 315-0027
Securities registered under Section 12(b) of the Exchange Act:
(Issuer’s Telephone Number, Including Area Code)
Title of Each Class
Common Stock, $0.15 par value
Title of Each Class
Common Stock, $0.15 par value
Securities registered under Section 12(b) of the Exchange Act:
Trading Symbol
AGX
Trading Symbol
AGX
Name of Each Exchange on Which Registered
The New York Stock Exchange (“NYSE”)
Name of Each Exchange on Which Registered
The New York Stock Exchange (“NYSE”)
Securities registered under Section 12(g) of the Securities Exchange Act of 1934 (the “Exchange Act”): None
Indicate by check mark if the Registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act of 1933. Yes ☐ No x
Securities registered under Section 12(g) of the Securities Exchange Act of 1934 (the “Exchange Act”): None
Indicate by check mark if the Registrant is not required to file reports pursuant to Section 13 or 15(d) of the Exchange Act. ¨
Indicate by check mark if the Registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act of 1933. Yes ☐ No x
Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act during the preceding 12 months (or for
Indicate by check mark if the Registrant is not required to file reports pursuant to Section 13 or 15(d) of the Exchange Act. ¨
such shorter period that the Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No ¨
Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act during the preceding 12 months (or for
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
such shorter period that the Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No ¨
during the preceding 12 months (or for such shorter period that the Registrant was required to submit such files). Yes x 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
Indicate by check mark whether the Registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company or an emerging growth
during the preceding 12 months (or for such shorter period that the Registrant was required to submit such files). Yes x No ¨
company. See the definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange
Indicate by check mark whether the Registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company or an emerging growth
Act.
company. See the definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange
Act.
Non-accelerated filer ¨
Large accelerated filer ¨
Accelerated filer x
Large accelerated filer ¨
Accelerated filer x
Emerging growth company ☐
Emerging growth company ☐
Non-accelerated filer ¨
If an emerging growth company, indicate by check mark if the Registrant has elected not to use the extended transition period for complying with any new or revised
financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
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
Indicate by check mark whether the Registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial
financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. Yes ☒
Indicate by check mark whether the Registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial
Indicate by check mark whether the Registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No x
reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. Yes ☒
The aggregate market value of the common stock held by non-affiliates of the Registrant was approximately $382,871,469 on July 30, 2021 (the last business day of the
Indicate by check mark whether the Registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No x
Registrant’s second fiscal quarter), based upon the closing price on the NYSE as reported for that date. Shares of common stock held by each officer and director and by each
The aggregate market value of the common stock held by non-affiliates of the Registrant was approximately $382,871,469 on July 30, 2021 (the last business day of the
person who owns 5% or more of the outstanding common shares have been excluded because such persons may be deemed to be affiliates. The determination of affiliate
Registrant’s second fiscal quarter), based upon the closing price on the NYSE as reported for that date. Shares of common stock held by each officer and director and by each
status is not necessarily a conclusive determination for other purposes.
person who owns 5% or more of the outstanding common shares have been excluded because such persons may be deemed to be affiliates. The determination of affiliate
Number of shares of common stock outstanding as of April 11, 2022: 14,815,609 shares.
status is not necessarily a conclusive determination for other purposes.
Number of shares of common stock outstanding as of April 11, 2022: 14,815,609 shares.
Portions of the Registrant’s Proxy Statement for the 2022 Annual Meeting of Stockholders to be held on June 21, 2022 are incorporated by reference in Part III.
DOCUMENTS INCORPORATED BY REFERENCE
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Registrant’s Proxy Statement for the 2022 Annual Meeting of Stockholders to be held on June 21, 2022 are incorporated by reference in Part III.
Smaller reporting company ☐
Smaller reporting company ☐
Table of Contents Table of Contents
ARGAN, INC. AND SUBSIDIARIES
2022 ANNUAL REPORT ON FORM 10-K
TABLE OF CONTENTS
PART I
ITEM 1. BUSINESS
ITEM 1A. RISK FACTORS
ITEM 1B. UNRESOLVED STAFF COMMENTS
PROPERTIES
ITEM 2.
ITEM 3. LEGAL PROCEEDINGS
PART II
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER
MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
ITEM 8.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
AND FINANCIAL DISCLOSURE
ITEM 9A. CONTROLS AND PROCEDURES
ITEM 9B. OTHER INFORMATION
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
ITEM 11. EXECUTIVE COMPENSATION
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
MANAGEMENT, AND RELATED STOCKHOLDER MATTERS
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR
INDEPENDENCE
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
ITEM 15. EXHIBITS AND FINANCIAL STATEMENTS
SIGNATURES
PART IV
PAGE
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Table of Contents
ITEM 1. BUSINESS.
PART I
Argan, Inc. (“Argan”) conducts operations through its wholly owned subsidiaries, Gemma Power Systems, LLC and
affiliates (“GPS”), Atlantic Projects Company Limited and affiliates (“APC”), The Roberts Company, Inc. (“TRC”) and
Southern Maryland Cable, Inc. (“SMC”) (together referred to as the “Company,” “we,” “us,” or “our”). Through GPS and
APC, the Company provides a full range of engineering, procurement, construction, commissioning, operations
management, maintenance, project development, technical and other consulting services to the power generation market
including the renewable energy sector. The wide range of customers includes independent power producers, public
utilities, power plant equipment suppliers and global energy plant construction firms with projects located in the United
States (the “U.S.”), the Republic of Ireland (“Ireland”) and the United Kingdom (the “U.K.”). GPS and APC represent the
Company’s power industry services reportable segment. Through TRC, the industrial fabrication and field services
reportable segment provides on-site services that support maintenance turnarounds, shutdowns and emergency
mobilizations for industrial plants primarily located in the southeastern region of the U.S. and that are based on its expertise
in producing, delivering and installing fabricated metal components such as piping systems and pressure vessels. Through
SMC, which conducts business as SMC Infrastructure Solutions, the telecommunications infrastructure services segment
provides project management, construction, installation and maintenance services to commercial, local government and
federal government customers primarily in the Mid-Atlantic region of the U.S.
Holding Company Structure
Argan was organized as a Delaware corporation in May 1961. We intend to make additional opportunistic acquisitions
and/or investments by identifying companies with significant potential for profitable growth and realizable synergies with
one or more of our existing businesses. However, we may have more than one industrial focus depending on the
opportunity. We expect that companies acquired by Argan will be maintained in separate subsidiaries that will be operated
in a manner that best provides cash flows for the Company and value for our stockholders. Argan is a holding company
with current investments in GPS, APC, TRC and SMC.
Power Industry Services
The most significant percentage of our power industry services has been performed by GPS which is a full-service
engineering, procurement and construction (“EPC”) services firm that we have operated for over fifteen years since it was
acquired by us in 2006. GPS has the proven abilities of designing, building and commissioning large-scale energy projects
in the U.S. The extensive design, construction, project management, start-up and operating experience of GPS has grown
with installed capacity exceeding 15 gigawatts of mostly domestic power-generating capacity. Our power projects have
included base-load combined-cycle facilities, simple-cycle peaking plants and boiler plant construction and renovation
efforts. We also have experience in the renewable energy sector by providing EPC contracting and other services to the
owners of alternative energy facilities, including biomass plants, wind farms and solar fields. Typically, the scope of work
for GPS includes complete plant engineering and design, the procurement of equipment and construction from site
development through electrical interconnection and plant testing. The durations of our construction projects typically range
between one to three years. However, the length of certain significant construction projects may exceed three years.
This reportable business segment also includes APC, a company formed in Ireland over 45 years ago, and its affiliated
companies, which we acquired in May 2015. APC provides turbine, boiler and large rotating equipment engineering,
procurement, installation, commissioning and outage services to primarily utility-scale power plant operators, major data
center operators, original equipment manufacturers and global construction firms. With its presence in Ireland, the U.K.
as well as the U.S., APC represents the portion of this segment’s business with an international focus.
The revenues of our power industry services business segment were $398.1 million, $319.4 million and $135.7 million for
the years ended January 31, 2022 (“Fiscal 2022”), 2021 (“Fiscal 2021”) and 2020 (“Fiscal 2020”), respectively, or 78%,
81% and 57% of our consolidated revenues for the corresponding periods, respectively. The substantial portions of the
revenues of this reportable segment reported for these three years were derived from the performance of activities by GPS
and APC under EPC services and other construction contracts with the owners of power plant projects.
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Table of Contents Guernsey Power Station
In January 2019, GPS entered into an EPC services contract to construct an 1,875 MW natural gas-fired power plant in
Guernsey County, Ohio (the “Guernsey Power Station”). Caithness Energy, L.L.C. (“Caithness”) led the development of
this project. After receiving a full notice-to-proceed, GPS commenced substantial activities for this project in August 2019.
The Guernsey Power Station is the largest, single-phase, gas-fired, power plant construction project in the U.S. For Fiscal
2022, Fiscal 2021 and Fiscal 2020, this project represented the major portions of consolidated revenues. Substantial
completion of this project is expected to occur during the second half of our fiscal year ending January 31, 2023 (“Fiscal
2023”).
Guernsey County is located in southeastern Ohio in the heart of the state’s Utica and Marcellus shale gas development
area. Using state-of-the-art combined cycle technology and an air-cooling system, the Guernsey Power Station will be a
cost-efficient, fuel-efficient, electricity generating power plant that protects air quality and conserves water with the
capability to satisfy the electricity needs of approximately one million homes.
The combined cycle design of this plant utilizes three power trains, with each one including a gas-fired turbine, a heat
recovery steam generator and a steam turbine, that will enable this plant to generate significantly more power from the
equivalent amount of fuel than a traditional gas-fired power plant. The Guernsey Power Station will also use dry cooling
technology to reduce water usage by as much as 95% compared to a water-cooled power plant. Because of its advanced
design, the power plant will achieve the lowest possible air emissions.
Maple Hill Solar
In May 2021, we announced that GPS entered into an EPC services contract with CPV Maple Hill Solar, LLC, an affiliate
of Competitive Power Ventures, Inc. (“CPV”), to construct the Maple Hill Solar facility. Project activities were begun by
GPS immediately. Project completion is currently scheduled to occur during the second half of Fiscal 2023. The unique
Maple Hill Solar project, which is located on previously cleared timber property in Cambria County, Pennsylvania, will
be constructed using over 235,000 photovoltaic modules to generate approximately 100 MW of electricity which is enough
to power more than 18,000 homes.
Kilroot Power Station
In October 2021, APC entered into an engineering and construction services contract with EPUKI London, U.K., which
is an affiliate of EPUKI, a Czech company, to construct a 2 x 330 MW natural gas-fired power plant in the Carrickfergus
area near Belfast, Northern Ireland, that will replace an existing coal-fired power plant at the site. The facility is being
developed by EPNI Energy Limited. A notice to proceed was received and project activities have commenced. The overall
project completion date is expected in the latter half of our fiscal year ending January 31, 2024 (“Fiscal 2024”).
Other APC Construction Works
The Irish operations of APC are performing the design, build and operations of a dedicated power plant within a major
data center. The size and configuration of the facility, consisting of up to nine (9) gas-fired turbines, is a first-of-a-kind
within the Irish data center market. The Irish operations are also completing construction activities for a major computer
chip manufacturer. Both of these Irish projects are located near Dublin.
As of January 31, 2022, the U.K. operations of APC have nearly completed the installation of a synchronized condenser
for the combined cycle, gas-fired power plant located at the Isle of Grain site in the Kent region of the U.K. Finally, during
Fiscal 2022, the U.K. operations of APC completed subcontracted construction efforts for the Teesside Renewable Energy
Plant (“TeesREP”) which is located in the northeast region of England. TeesREP is a 299 MW biomass-fueled power
station that will burn primarily wood pellets in order to generate electricity sufficient to power 600,000 homes. APC was
responsible primarily for the mechanical installation of the boiler for one of the largest bio-mass-fueled power stations in
the world.
Major Customer Contracts
At January 31, 2022, the project backlog for this reporting segment was approximately $0.7 billion. The comparable
backlog amount as of January 31, 2021 was approximately $0.8 billion. Our reported amount of project backlog at a point
in time represents the total value of projects awarded to us that we consider to be firm as of that date less the amounts of
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Table of Contents revenues recognized to date on the corresponding projects. The project backlog amount that we disclose is larger than the
value of remaining unsatisfied performance obligations, or RUPO, on active contracts (see Note 4 to the accompanying
consolidated financial statements). As of January 31, 2022, the difference between the amount of project backlog of $0.7
billion and the lesser RUPO amount of $0.4 billion is the EPC services contract with ESC Harrison County Power, LLC,
that is described below.
Typically, we include the total value of EPC services and other major construction contracts in project backlog when we
receive a corresponding notice to proceed from the project owner. However, we may include the value of an EPC services
contract prior to the receipt of a notice to proceed if we believe that it is probable that the project will commence within a
reasonable timeframe, among other factors. Projects that are awarded to us may remain included in our backlog for
extended periods of time as customers experience project delays.
As we have discussed at previous reporting dates, GPS has been awarded other EPC services contracts for which
commencement of project activities have been delayed. We have maintained that the delays in the construction starts of
these projects and the awards of new business awards to GPS relate to a variety of factors, especially in the northeastern
and Mid-Atlantic regions of the U.S. where the electricity grid is run by PJM Interconnection LLC (“PJM”). Certain
projects in development are confronting difficulties in obtaining the necessary permits for construction and operation, in
securing the delivery of fuel to the power plant site and in establishing the necessary power connection to the electricity
grid. Currently, we believe that the ability of the owners of fully developed gas-fired power plant projects to close on
equity and permanent debt financing is challenged by uncertainty in the capital markets caused by multiple factors
including delayed capacity auctions and mounting public and political opposition to fossil-fuel energy projects.
In January 2020, GPS entered into an EPC services contract with Harrison Power, LLC (“Harrison Power”) to construct a
1,085 MW natural gas-fired power plant in the Village of Cadiz, Harrison County, Ohio. The project is being developed
by EmberClear, the parent company of Harrison Power, and Advanced Power Services (NA) Inc. We anticipate adding
the value of this contract to project backlog closer to its financial close and expected start date. Previously, we anticipated
that the start of construction activities for this project would occur before the end of Fiscal 2022. However, the start dates
for construction are generally controlled by the project owners and certain delays prevented the start of this project from
occurring during Fiscal 2022. Nevertheless, as the project owners have continued to progress their activities, we are
cautiously optimistic that the start of construction activities for this project will occur before the end of Fiscal 2023.
In May 2019, GPS entered into an EPC services contract to construct a 625 MW power plant in Harrison County, West
Virginia. Caithness is partnered with ESC Harrison County Power, LLC to develop this project. As a limited notice to
proceed with certain preliminary activities was received from the owner of this project at the time, the value of the contract
was added to our project backlog. However, meaningful project development activities for the facility appear to be limited.
We believe that it is significant that this project is included in the new services queue of PJM with a recently updated status
indicating work is being performed by PJM to assure the plant’s interconnection to the electricity grid. Nonetheless, if
meaningful development milestones are not achieved, our evaluation may result in the removal of the value of this power
plant from project backlog during Fiscal 2023.
On March 12, 2020, we announced that GPS had entered into an EPC services contract with NTE Connecticut, LLC to
construct the Killingly Energy Center, a 650 MW natural gas-fired power plant, in Killingly, Connecticut. The facility is
being developed by NTE Energy, LLC (“NTE”). However, in November 2021, the New England electricity grid operator
requested that the Federal Energy Regulatory Commission (“FERC”) grant it permission to terminate its capacity supply
contract with NTE because it did not believe that NTE would meet its critical path schedule milestones as required;
permission was subsequently granted. This termination has significantly reduced the likelihood that this power plant will
be built.
As announced in Fiscal 2019, GPS entered into an EPC services contract to construct the Chickahominy Power Station, a
1,740 MW natural gas-fired power plant, in Charles City County, Virginia. We did not include the value of this contract
in our project backlog. We provided financing through notes receivable from the consolidated VIE that was established
by the project owner and that was dedicated to the development efforts. We also provided technical support to the project.
Significant development milestones were achieved by the project owner. However, a planned gas pipeline expansion that
the project owner believed would supply natural gas to the power plant was rejected by Virginia’s State Corporation
Commission during Fiscal 2022, which led to cancellation by PJM of its interconnection service agreement with the project
based on alleged failures of the project to meet required milestones. In February 2022, PJM received notice from FERC
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Table of Contents accepting PJM’s termination of the service agreement which effectively removed the Chickahominy Power Station from
PJM’s planning queue. In summary, the project owner was unable to secure an alternative fuel-supply for the plant and
the project lost its interconnection service commitment from PJM. Therefore, the project owner was unable to obtain the
necessary equity financing for the project and we ceased providing project development funding. We concluded that the
completion of the development of this project is significantly jeopardized and that it is doubtful that construction of this
power plant will occur. In March 2022, the project owner issued a public statement that the project was cancelled (see
additional discussion regarding this matter below in the “Special Purpose Entities” section).
We believe that it is important to note that the owners of two of our contracted natural gas-fired power plant projects have
plans to integrate green hydrogen solution packages developed by a major gas turbine manufacturer. While the plants will
initially burn natural gas alone, it is planned by the respective project owners that the plants will eventually burn a mixture
of natural gas and green hydrogen, thereby establishing power-generation flexibility for these plants.
Despite our commitment to the construction of state-of-the-art, natural gas-fired power plants as important elements of our
country’s electricity-generation mix in the future, we are targeting business development efforts to win projects for the
erection of utility-scale wind farms and solar fields and for the construction of other renewable energy projects. We have
successfully completed these types of projects in the past and we are renewing efforts to obtain new work in the renewable
power sector that will complement our natural gas-fired EPC services projects going forward, like the Maple Hill Solar
energy project.
Special Purpose Entities
We selectively participate in power plant project development and related financing activities 1) to maintain a proprietary
pipeline for future EPC services contract opportunities, 2) to secure exclusive rights to EPC contracts, and 3) to generate
profits through interest income and project development success fees. EPC contractors in our industry also periodically
execute certain contracts jointly with third parties through joint ventures, limited partnerships and limited liability
companies for the purpose of completing a project or program for a project owner. These special purpose entities are
generally dissolved upon completion of the corresponding project or program.
In January 2018, we determined that we were the primary beneficiary of a VIE that was performing the project
development activities related to the construction of the Chickahominy Power Station. The account balances of the VIE
have been included in the consolidated financial statements since then, including capitalized project costs that have been
included in property, plant and equipment. After reaching the conclusions discussed above and consistent with the
disclosure included in the Current Report on Form 8-K that we filed on January 24, 2022, we recorded an impairment loss
during the fourth quarter of Fiscal 2022 related to all of the capitalized project development costs in the amount of $7.9
million, of which $2.5 million was attributed to the non-controlling interest.
Labor and Materials
We perform work on job sites in different states and countries. The skilled craft labor pool is unique in each region due to
a variety of factors, including union versus non-union work environments, competing infrastructure projects located nearby
our sites that utilize the same labor pool as us, and decreased and aging labor pools resulting from demographic trends. As
such, we take a carefully considered and tailored approach at each job site to acquire and retain the required personnel
resources when we need them, especially craft labor, and to maintain optimum productivity on each of our projects.
Depending on the project, we may utilize direct hires, subcontractors, existing internal personnel, or a combination of the
three. To date, we have managed generally to staff each of our jobs safely and effectively.
Overall, employment in the domestic construction industry is nearing the pre-pandemic high. The industry’s
unemployment rate has dropped to 6.7% for February 2022. The number of unemployed job seekers with construction
experience has declined by about 26% over the last year. The rising employment has been accompanied by higher wages
that have risen by approximately 5.1% over the last year as well.
However, in staffing each new project with the skilled craft labor needed to complete the job successfully, we may be
challenged by labor shortages in the construction industry, rising wages, demographic trends and other factors. Going
forward, competition for labor may include employers outside the construction industry that can offer the one job benefit
that construction companies can’t which is the opportunity to work remotely. In short, labor shortages are expected to
persist into the next fiscal year as wages rise.
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Table of Contents In connection with the engineering and construction of traditional power plants, biodiesel plants and other renewable
energy systems, we procure materials for installation on our various projects. We are not dependent upon any one source
for major equipment components, like heat recovery steam generation units, steam turbines and air-cooled condensers, or
any other construction materials that we use to complete a particular power project. In general, we have not experienced
significant schedule delays related to the procurement or delivery of the necessary materials for our major projects in the
past.
With our assistance, project owners frequently procure and supply certain major components of the power plants such as
state-of-the-art natural gas turbines. We have significant experience in delivering EPC projects with the latest turbine
technology and working with all three major gas-fired turbine manufacturers to meet each project owner’s specific power
plant requirements. EPC project requirements may vary considerably. Our personnel possess the skills and experience
needed to overcome the plant design, development and construction challenges presented by each EPC services project,
thereby steadily eliminating uncertainties throughout the development lifecycle and construction phases of each project.
We sourced certain supplies, materials and equipment from countries stricken by the COVID-19 pandemic, as did certain
of the major original equipment manufacturers for major components of natural gas-fired power plants. Disruptions to
these supply chains, or the supply and productivity of labor at job sites, due to the global COVID-19 pandemic or other
causes may continue to challenge our schedules, and may ultimately affect our ability to complete our large fixed-price
contract projects in accordance with original schedules. For example, the supply of solar panels to projects in the U.S has
been slowed. We believe that we have protections in our contracts with major customers that provide certain relief that
helps to mitigate certain financial risks. These protections could be limited depending on the underlying issues and the
financial challenges of our customers.
The extent of the operational and financial impacts on us probably will depend on how long and widespread the disruptions
prove to be. As we go forward, there may be unscheduled delays in the delivery of materials and equipment ordered by us
or a project owner or other unanticipated challenges to our ability to complete major job tasks when planned, among other
impacts, none of which are quantifiable at this time. We have actively attempted to manage these risks during this period
of uncertainty regarding the duration and extent of the COVID-19 outbreak.
The costs of materials needed for the completion of our projects may fluctuate from time to time. In times of increased
volatility similar to those being experienced currently, we take steps to reduce our risks. For example, we may hold quotes
related to materials in our industrial fabrication and field services segment for only three days. For major fixed price
contracts in our power industry services segment, we may mitigate material cost risks by procuring the majority of the
equipment and construction supplies during the early phases of a project. During Fiscal 2022, we believe in general that
we effectively confronted the economic challenges to our active jobs from the global surge in material costs.
While our operations were challenged by the well-publicized global supply chain disruptions during Fiscal 2022, the
management of the risks associated with the inability to obtain machinery, equipment and other materials when needed
continued to include our best efforts. However, we are concerned that the supply chain uncertainties may be impacting
project owners’ confidence in commencing new work which may adversely affect our expected levels of revenues until
the supply chain disruptions dissipate.
Competition
GPS competes with large and well capitalized private and public firms in the construction and engineering services industry
like Kiewit Corporation, one of the largest construction firms in the country, and other global firms providing engineering,
procurement, construction and project management services. These and other competitors are multi-billion-dollar
companies that may have thousands of employees. We also may compete with regional construction services companies
in the markets where planned projects might be located. Typically, a condition for award is that the contractor perform on
a fixed-price or lump-sum contract basis; smaller elements of a contract may be billable on an allowance or cost-
reimbursable basis. As explained below, there are risks of unrecovered costs, among other features, associated with these
types of contracts.
To compete with these firms, we emphasize our proven track record as a value-add choice for the design, build and
commissioning of natural gas-fired and alternative energy power systems. Our successful experience includes the efficient
completion and maintenance of natural gas-fired combined cycle and simple cycle power plants, wood/coal-fired plants,
waste-to-energy plants, wind farms, solar fields and biofuel processing facilities, most performed on an EPC contract basis.
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Table of Contents Through the power industry services segment, we provide a full range of competitively priced development, consulting,
engineering, procurement, construction, commissioning, operations management and maintenance services to project
owners. We are able to react quickly to their requirements while bringing a strong, experienced team to help navigate
through difficult technical, scheduling and construction issues. We believe that the cultures of GPS and APC encourage
motivated, creative, high energy and customer-focused teams that deliver results. Our projects are directed by dedicated
on-site project management teams and our project owner customers have direct access to our senior management at these
companies.
APC also competes regularly with much bigger, more well-established companies for larger projects. These companies
include the John Wood Group PLC and METKA, the sustainable engineering solutions business unit of Mytilineos S.A.
Our competition for domestic renewable energy projects like solar energy fields and land-based wind energy farms is more
diverse and may include firms that are smaller than us.
The competitive landscape in the EPC services market for natural gas-fired power plant construction has changed
significantly over the last five (5) years. While the market remains dynamic, we are moving into an era where there may
be fewer competitors for new domestic gas-fired power plant EPC services project opportunities. Several major
competitors have exited the market for a variety of reasons or have been acquired. Others have announced intentions to
avoid entering into fixed-price contracts.
Nonetheless, fixed-price contracting in the U.S. has continued to occur due to intense competition that has increased the
bargaining power of project owners and sustained the number of projects typically completed on a fixed-price basis.
Competition has led to aggressive bidding on projects while certain contractors have accepted greater risks associated with
the inability to anticipate unforeseen issues and the failure to include adequate contingencies to cover lower-than expected
labor productivity, unfavorable execution challenges and unusual weather events, for example. As a result, construction
and engineering companies have incurred losses related to performance on fixed-price contracts, including some of the
largest firms in the country.
We are not immune to these risks. As described extensively in prior reports, we incurred a loss in connection with the
performance of the fixed price portion of our TeesREP subcontract in the final amount of $29.5 million. Nonetheless, we
try to be particularly selective in pursuing new project opportunities and are reluctant to enter into fixed-price contracts
with perceived high-risk profiles. The track record of GPS has proven that fixed-price contracts can provide opportunities
for higher margins if the corresponding projects are completed at lower-than-planned costs. We are confident that our
project management teams have gained the experience necessary for successful execution on these types of contracts as
we go forward although we are aware of the risks involved.
Over the past few years, GPS has provided top management guidance and project management expertise to APC as it
completed its subcontract efforts for the TeesREP power plant and won the award of the project to build the new gas-fired
power plant in Northern Ireland. APC has provided project management manpower to GPS on several of its EPC services
contracts. These recent experiences have demonstrated that the two companies can combine resources effectively. We
expect that GPS and APC will continue to work together in the future given the apparent emerging new business
opportunities in the U.K. and Ireland, the strength of the reputation of GPS for successfully completing large gas-fired
power plant projects in the U.S. and the growing recognition in the power community in the British and Irish islands that
APC is committed to and capable of tackling larger and more complex power projects.
Customers
For Fiscal 2022 and Fiscal 2021, our most significant customer was Guernsey Power Station LLC, the owner of the
Guernsey Power Station project, which accounted for approximately 57% and 67% of our consolidated revenues for the
corresponding years. For Fiscal 2020, the Company’s most significant power industry services customers were the owner
of the Guernsey Power Station project and Técnicas Reunidas UK Limited, APC’s customer on the TeesREP project. Each
customer accounted for more than 10% of our consolidated revenues and together they represented 37% of consolidated
revenues for the year.
No other customer of this reportable segment represented greater than 10% of consolidated revenues for Fiscal 2022, Fiscal
2021 or Fiscal 2020.
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Table of Contents Regulation
Our power industry services operations are subject to various federal, state, local and foreign laws and regulations
including: licensing for contractors; building codes; permitting and inspection requirements applicable to construction
projects; regulations relating to worker safety and environmental protection; and special bidding, procurement and
employee compensation requirements. Many state and local regulations governing construction require permits and
licenses to be held by individuals who have passed an examination or met other requirements. We believe that we have all
the licenses required to conduct our current operations and that we are in substantial compliance with applicable regulatory
requirements.
The power plants that we build, and other energy facilities including the pipelines required to supply natural gas fuel to
them, are also subject to a myriad of federal and state laws and regulations governing environmental protection, air quality,
water quality and noise and height restrictions. The growing preference for renewable energy sources and the elimination
of fossil-fueled power plants by the populations of the U.S. and the U.K. may result in such restrictions becoming more
severe in the future. The consequences may result in fewer gas-fired power plants being constructed in the future than are
currently forecast offset by an increased number of renewable power facility opportunities.
Relating to the COVID-19 pandemic and its apparent decline in the U.S. and Western Europe, local and national
government health agencies in the U.S., the U.K. and Ireland are easing the onerous restrictions on places and/or events
where people may gather in close proximity to others. However, the occurrence of severe future outbreaks where our
projects are located would most likely result in the reinstatement of such restrictions which could severely hamper our
abilities to conduct construction activities on job-sites, or could shut-down such sites completely. However, we do believe
that our office-based employees have demonstrated the ability to work effectively on a remote basis, if necessary, for
extended periods of time.
Industrial Fabrication and Field Services
TRC was founded in 1977 and is located near Greenville, North Carolina. TRC is principally an industrial field services
provider and pipe and vessel fabricator for industrial organizations primarily in the southeast region of the U.S. Its facilities
include two metal fabrication plants and support structures. TRC operates within its own reportable business segment,
industrial field services and fabrication. Industrial field services typically represent over 75% of TRC’s annual revenues
with the remaining revenues contributed by projects performed in its two metal fabrication plants.
The major customers of TRC include large fertilizer companies such as Nutrien Ltd.; a gold-mining company located in
South Carolina, OceanaGold Corporation; a world leading supplier of industrial gases, Air Liquide S.A.; North America’s
largest forest products companies such as Weyerhaeuser Company and Domtar Corporation; and various other industrial
companies. For Fiscal 2022, Fiscal 2021 and Fiscal 2020, TRC reported revenues of $97.9 million, $65.3 million and
$94.7 million, respectively, or approximately 19%, 17% and 40% of consolidated revenues for the corresponding years,
respectively.
TRC increased its income from operations to $8.3 million for Fiscal 2022 from $0.6 million for Fiscal 2021. TRC has
achieved positive earnings before interest, taxes, depreciation and amortization (“EBITDA”), for each of the past six years
of operations although the financial performance over this period has been uneven and inconsistent. Based on the current
backlog and number of new business opportunities, we expect that TRC will report favorable results again for the newly
commenced fiscal year.
Since the acquisition of TRC, we have provided it with $9.0 million in net cash so that it could fund the completion of the
work on certain loss contracts in progress on the date of the acquisition, enhance working capital in support of business
growth and stability, acquire capital equipment to assure efficient and competitive fabrication and field operations and
support other general corporate needs. TRC has periodically returned cash to Argan and no cash has been advanced to
TRC since May 2019.
The latest business valuations of TRC did not result in any goodwill impairment losses for Fiscal 2022 or Fiscal 2021. The
uneven operating results of TRC did result in a series of prior year goodwill impairment losses. The originally established
balance of the goodwill of TRC, $14.4 million, has been written down to a net balance of $9.5 million as of January 31,
2022.
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Table of Contents The impacts of COVID-19 did result in delays in certain contract awards and project starts which resulted in revenue
shortfalls for Fiscal 2021. However, effective business development efforts have rebuilt the project backlog of TRC which
has been grown over the last two years by $30.5 million to $44.5 million as of January 31, 2022.
Telecommunications Infrastructure Services
SMC represents our telecommunications infrastructure services reportable business segment and conducts business as
SMC Infrastructure Solutions, which provides comprehensive technology wiring and utility construction solutions to
customers primarily in the Mid-Atlantic region of the U.S. We perform both outside and inside plant cabling.
Services provided to our outside premises customers include trenchless directional boring and excavation for underground
communication and power networks, aerial cabling services, and the installation of buried cable, high and low voltage
electric lines, and private area outdoor lighting systems. The outside premises services are primarily provided to state and
local government agencies, regional communications service providers, electric utilities and other commercial customers.
The wide range of inside premises wiring services that we provide to our customers include structured cabling,
terminations and connectivity that provide the physical transport for high-speed data, voice, video and security networks.
These services are provided primarily to federal government facilities, including cleared facilities, on a direct and
subcontract basis. Such facilities typically require regular upgrades to their wiring systems in order to accommodate
improvements in security, telecommunications and network capabilities.
Consistently, a major portion of SMC’s revenue-producing activity each year is performed pursuant to task or work orders
issued under master agreements with SMC’s major customers such as Southern Maryland Electric Cooperative, a local
electricity cooperative. Over the last three years, other major customers have included counties and municipalities located
in Maryland; certain state government agencies in Maryland; and technology-oriented government contracting firms in the
Washington, D.C. metropolitan area.
The revenues of SMC were $13.4 million, $7.6 million and $8.6 million for Fiscal 2022, Fiscal 2021 and Fiscal 2020,
respectively, or approximately 3%, 2% and 3% of our consolidated revenues for the corresponding years, respectively.
Late in Fiscal 2022, SMC acquired the business of Lee Telecommunications, Inc. (“LTI”) for consideration of $0.6 million
in cash, which expanded the business footprint of SMC into the Tidewater area of Virginia. LTI provides a suite of
communications infrastructure services similar to those provided by SMC. The largest customer of LTI is Newport News
Shipbuilding, a division of Huntington Ingalls Industries, to which it has been providing services since 1995.
The combined operations of SMC operate in the fragmented and competitive telecommunication and infrastructure
services industry. We compete with providers ranging from regional companies to larger firms servicing multiple regions,
as well as large national and multi-national contractors. We believe that we compete favorably with the other companies
in our market space by emphasizing our high-quality reputation, outstanding customer base, security-cleared personnel
and highly motivated work force in competing for larger and more diverse contracts. Based on its reputation and quality
performance, SMC was selected on a sole source basis to perform outside premises and structured cabling work at several
secure overseas locations during Fiscal 2022, Fiscal 2021 and Fiscal 2020.
Employees
The total number of personnel employed by us is subject to the volume of construction in progress and the relative amount
of work performed by subcontractors. We had 1,358 employees at January 31, 2022, substantially all of whom were full-
time. We believe that our employee relations are generally good.
Financing Arrangements
During April 2021, we amended our Amended and Restated Replacement Credit Agreement (the “Credit Agreement”)
with Bank of America (the “Bank”). The amendment extended the expiration date of the Credit Agreement to May 31,
2024 and reduced the borrowing rate. The Credit Agreement, as amended, includes the following features, among others:
a lending commitment of $50.0 million including a revolving loan with interest at the 30-day LIBOR plus 1.6% (reduced
from 2.0%), and an accordion feature which allows for an additional commitment amount of $10.0 million, subject to
certain conditions. We may also use the borrowing ability to cover other credit instruments issued by the Bank for our use
in the ordinary course of business as defined in the Credit Agreement.
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Table of Contents At January 31, 2022, the Company did not have any borrowings outstanding under the Credit Agreement. However, the
Bank has issued letters of credit in the total outstanding amount of $21.5 million in support of the activities of APC under
new customer contracts.
The Company has pledged the majority of its consolidated assets to secure its financing arrangements. The Bank’s consent
is not required for acquisitions, divestitures, cash dividends or significant investments as long as certain conditions are
met. The Bank requires that the Company comply with certain financial covenants at its fiscal year-end and at each of its
fiscal quarter-ends. The Credit Agreement, as amended, includes other terms, covenants and events of default that are
customary for a credit facility of its size and nature, including a requirement to achieve positive adjusted consolidated
EBITDA, as defined, over each rolling twelve-month measurement period. As of January 31, 2022 and January 31, 2021,
the Company was in compliance with the covenants of the Credit Agreement.
Financial markets around the globe are preparing for the pending discontinuation of LIBOR, which is the widely used
indicator of basis for short-term lending rates. The transition from LIBOR is market driven, not a change required by
regulation. The U.S. and other countries are currently working to replace LIBOR with alternative reference rates. We do
not expect that the replacement of LIBOR as the basis for the determination of our short-term borrowing rate will have
any significant effects on our financial arrangements with the Bank or our financial reporting.
Safety, Risk Management, Insurance and Performance Bonds
We are committed to ensuring that the employees of each of our businesses perform their work in a safe environment. We
regularly communicate with our employees to promote safety and to instill safe work habits. GPS, APC, TRC and SMC
each has an experienced full-time safety director committed to ensuring a safe work place, as well as compliance with
applicable permits, insurance and local and environmental laws. Our OSHA reportable incident rates, weighted by hours
worked for all of our subsidiaries, were 0.48, 0.55 and 0.40 for calendar years 2021, 2020 and 2019, respectively; our rates
were significantly better than the national average rates in our industry (NAICS – 2379) for those years.
We retain qualified insurance brokerage assistance in the regular evaluation of the adequacy of insurance coverage
amounts and the annual negotiation of premium amounts in the areas of property and casualty insurance, general liability,
umbrella coverage, director and officer insurance and other specialty coverages. We believe that our insurance coverage
amounts are adequate, but not excessive, and provide the proper amounts of coverage where we believe insurable risks
may exist.
Contracts with customers in each of our reportable business segments may require performance bonds or other means of
financial assurance to secure contractual performance. We maintain material amounts of cash, cash equivalents and short-
term investments, and, as indicated above, we have the commitment of the Bank to issue irrevocable standby letters of
credit up to an aggregate amount of $50.0 million in support of our bonding collateral and other business requirements.
As of January 31, 2022, the revenue value of our unsatisfied bonded performance obligations was approximately $235.1
million. In addition, there were bonds outstanding in the aggregate amount of approximately $1.0 million covering other
risks including our warranty obligations related to completed activities. Not all of our projects require bonding.
Environmental, Social, and Governance (“ESG”) Matters
Our on-going commitment to environmental, health and safety, corporate social responsibility, corporate governance,
sustainability, and other public policy matters relevant to us is being supported by the ESG subcommittee of our board of
directors, which was formed in Fiscal 2021. Its charter requires it to assist our senior management in: (a) setting our general
strategy relating to ESG matters, as well as developing, implementing, and monitoring initiatives and policies for us based
on that strategy; (b) overseeing communications with employees, investors, and other stakeholders with respect to ESG
matters; and (c) anticipating and monitoring developments relating to, and improving management’s understanding of,
ESG matters.
A summary of our ESG accomplishments in various areas over the past three years follows:
• We refreshed our Code of Conduct to strengthen the comprehensive anti-corruption, anti-discrimination and anti-
harassment sections, to emphasize respect for human rights, and to make other updates;
• We increased the percentage of independent members of our board of directors while increasing its diversity;
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Table of Contents • We made investments in solar energy funds to secure portions of the available investment tax credits and tax
depreciation, which facilitated the construction and deployment of multiple solar arrays;
• We made lighting and other energy efficiency upgrades at the office building that we own while our employees
continue to participate in available recycling programs at all of our facilities; and
• We commenced a solicitation of recommendations from our employees by an ESG cross-subsidiary working
group in order to identify additional actionable items including coordinated community service projects. As a
result, employees from all levels of our Company have participated in projects such as Habitat for Humanity,
Toys for Tots, school supply drives and Company-sponsored youth programs, while supporting meaningful
apprenticeships and internships within our companies.
A significant amount of effort was spent by senior and project management to ensure the safety of our employees during
the COVID-19 pandemic while we continued to satisfy our customer obligations. While our pro-active efforts varied
depending on the particular job or office location, and other factors including the severity of the outbreak, we implemented
a number of different safety measures, including COVID-19 on-site testing at major job sites, remote work, staggered
shifts in various offices, contract tracing and quarantines.
As an important element of our business development strategy, we are targeting a number of contract awards that will
expand the amount of our renewable energy project work. In May 2021, GPS commenced activities pursuant to the EPC
services contract to construct the Maple Hill Solar facility, which we believe will be among the largest solar-powered
energy plants in Pennsylvania. For Fiscal 2022 and Fiscal 2021, the amounts of revenues earned by us and associated with
renewable energy projects were 13.4% and 10.8% of corresponding revenues for the power industry services segment. We
expect that revenues associated with the performance of renewable energy projects will become a more meaningful
percentage of our segment and consolidated revenues over the coming years.
Meanwhile, we believe that our gas-fired power plant construction business is valuable to the achievement of the net
carbon emission reduction goals of the U.S., the U.K. and Ireland as we are recognized as an accomplished, dependable
and cost-effective provider of construction services to gas-fired power plant owners.
Like the U.S., the U.K. and Ireland are committed to the increase in energy consumption sourced from wind and the sun
on the pathway to net zero emissions. In those countries, there appears to be recognition that these sources of electrical
power are inherently variable. Other technologies will be required to support these power sources and to provide electricity
when power demands exceed the amount of electricity supplied by renewable energy sources. The existence of the
necessary power reserve during the long transition period to zero emissions will require supporting conventional power
generation sources, typically natural gas-fired power plants.
The Irish government has issued a policy statement on the security of the electricity supply in Ireland which confirms the
requirement for the development of new support technologies to deliver on its commitment to have 80% of the country’s
electricity generated from renewables by 2030. The report emphasizes that this will require a combination of conventional
generation (typically powered by natural gas), interconnection to other jurisdictions, demand flexibility and other
technologies such as energy storage (i.e., batteries) and generation from renewable gases (i.e., biomethane and/or hydrogen
produced from renewable sources). The Irish government has announced that the development of new conventional
generation (including gas-fired generation) is a national priority and should be permitted and supported in order to ensure
the security of electricity supply while supporting the growth of renewable electricity generation.
In the U.S., it is fact that power plant carbon emissions declined by 35% during the period 2010 through 2020. The primary
reason for this decline was the replacement of coal-fired power plants with efficient gas-fired power plants. Natural gas is
relatively clean burning, cost-effective and reliable.
Materials Filed with the Securities and Exchange Commission
The public may read any materials that we file with the Securities and Exchange Commission (the “SEC”) at the SEC’s
public reference room at 100 F Street, NE, Washington, D.C. 20549. The public may obtain information on the operation
of the public reference room by calling the SEC at 1-800-SEC-0330. The SEC maintains an Internet site that contains
reports, proxy and information statements and other information regarding issuers that file electronically with the SEC,
including us, at http://www.sec.gov.
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Table of Contents
We maintain a website on the Internet at www.arganinc.com that includes access to financial data. Information on our
website is not incorporated by reference into this Annual Report on Form 10-K for the fiscal year ended January 31, 2022
(the “2022 Annual Report”). Copies of our Annual Reports on Form 10-K, our Quarterly Reports on Form 10-Q, our
Current Reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the
Exchange Act, as well as our Proxy Statements, are available, as soon as reasonably practicable, after we electronically
file such materials with, or furnish them to, the SEC, without charge and upon written request provided to our Corporate
Secretary at Argan, Inc., One Church Street, Suite 201, Rockville, Maryland 20850.
ITEM 1A. RISK FACTORS.
Our business is challenged by a changing environment that involves many known and unknown risks and uncertainties.
The risks described below discuss factors that have affected and/or could affect us in the future. There may be others. We
may be affected by risks that are currently unknown to us or are immaterial at this time. If any such events did occur, our
business, financial condition and results of operations could be adversely affected in a material manner. Our future results
may also be impacted by other risk factors listed from time to time in our future filings with the SEC, including, but not
limited to, our Annual Reports on Form 10-K and our Quarterly Reports on Form 10-Q. As the most significant portion of
our consolidated entity is represented by the power industry services reportable business segment, the risk factor
discussions included below are focused on that business. However, as a large number of these same risks exist for our
other reportable segments, (1) industrial fabrication and field services, and (2) telecommunications infrastructure services,
a review and assessment of the following risk factors should be performed with that in mind.
This section of our 2022 Annual Report may include projections, assumptions and beliefs that are intended to be “forward
looking statements.” They should be read in light of our cautionary statement regarding “forward looking statements” that
is presented in Item 7 of this 2022 Annual Report.
Risks Related to Our Business
Demand for our services may decrease during economic downturns or unpredictable economic cycles, which would most
likely affect our businesses adversely.
Substantial portions of the revenues and profits earned by our reportable business segments are generated from
construction-type projects, the awarding and/or funding of which we do not directly control. The engineering and
construction industry historically has experienced cyclical fluctuations in the levels of construction activity due to
economic recessions, downturns in the business cycles of project owners, material shortages, price increases by
subcontractors, interest rate fluctuations, and other economic factors beyond our control. When the general level of
economic activity deteriorates, the level of uncertainty about future business prospects rises. When this occurs, customers
may delay or cancel new projects, maintenance on major power plant components, repairs to damaged or worn equipment
or other plant outage work. The adverse financial condition of the industry could negatively affect our customers and their
willingness to fund capital expenditures or other major projects in the future. Economic, regulatory and market conditions
affecting our specific customers may adversely impact the demand for our services, resulting in the delay, reduction or
cancellation of certain projects on which our forecasts of future business may depend.
Future revenues are dependent on the awards of new EPC projects to us, the receipt of corresponding full notices-to-
proceed and our ability to successfully complete the projects that we start.
The majority of our consolidated revenues relate to performance by the power industry services segment which represented
78%, 81% and 57% of consolidated revenues for Fiscal 2022, Fiscal 2021 and Fiscal 2020, respectively. Due primarily to
the generally favorable operating results of GPS, the major business component of this segment, we have generated
consolidated net income for eleven of the last twelve years. GPS earns the substantial portion of its revenues from execution
on long-term EPC services contracts with project owners.
Revenues of this segment increased by 25% to $398.1 million for Fiscal 2022 from revenues of $319.4 million for Fiscal
2021. This segment reported income from operations in the amount of $44.7 million for Fiscal 2022 compared with a
corresponding amount of $30.6 million for Fiscal 2021, an increase of approximately 46%.
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Table of Contents
For Fiscal 2022 and Fiscal 2021, a majority portion of consolidated revenues related to EPC services provided to a single
power industry service customer on a project that is scheduled to be substantially completed during the second half of
Fiscal 2023. During the period from Fiscal 2019 to the end of Fiscal 2021, GPS was awarded EPC services contracts for
the construction of seven combined cycle, gas-fired power plants with an aggregate value of approximately $3.0 billion.
However, we have received a full notice to proceed for only one of these EPC projects, a second project for the construction
of a natural gas-fired power plant in West Virginia was cancelled during Fiscal 2021 by the project owner, and a third
power plant project, located in Virginia, was recently cancelled by its owner.
Our ability to sustain revenues depends on many factors including the ability of the power industry services business to
not only win the awards of significant new EPC projects, but to obtain the corresponding full notices-to-proceed and to
complete its projects successfully. There is always a possibility that one or more of the pending EPC services projects will
not be built. Should we fail to commence construction activities during Fiscal 2023 on one or more of the major projects
included in our current group of awarded contracts or on a newly awarded contract, the growth in revenues and profits that
we expect for Fiscal 2023 will be adversely affected.
Our dependence on large construction contracts may result in uneven financial results.
Our power industry service activities in any one fiscal reporting period are concentrated on a limited number of large
construction projects for which we recognize revenues over time as we transfer control of the project asset to the customer.
To a substantial extent, our contract revenues are based on the amounts of costs incurred. As the timing of equipment
purchases, subcontractor services and other contract events may not be evenly distributed over the terms of our contracts,
the amount of total contract costs may vary from quarter to quarter, creating uneven amounts of quarterly and/or annual
consolidated revenues. In addition, the timing of contract commencements and completions may exacerbate the uneven
pattern. As a result of the foregoing, future reported amounts of consolidated revenues, cash flow from operations, net
income and earnings per share may vary in an uneven pattern and may not be indicative of the operating results expected
for any other fiscal period, thus rendering consecutive quarter comparisons of our consolidated operating results a less
meaningful way to assess the growth of our business.
Actual results could differ from the assumptions and estimates used to prepare our consolidated financial statements.
To prepare consolidated financial statements in conformity with accounting principles generally accepted in the U.S., we
are required to make estimates, assumptions and judgments as of the date of such financial statements, which affect the
reported values of assets and liabilities, revenues and expenses, and disclosures of contingent assets and liabilities. For
each of our fixed price customer contracts, we recognize revenues over the life of the contract as performance obligations
are completed by us based on the proportion of costs incurred to date compared to the total costs estimated to be incurred
for the entire project, and by using the resulting percentage to update the recorded amounts of project-to-date revenues.
We review and make necessary revisions to the amounts of estimated future costs on a monthly basis. In addition, contract
results may be impacted by our estimates of the amounts of change orders that we expect to receive and our assessment of
any contract disputes that may arise.
The effects on revenues of changes to the amounts of contract values and estimated costs typically will be recorded as
catch-up adjustments when the amounts are known and can be reasonably estimated. These revisions can occur at any time
and could be material. Given the uncertainties associated with the types of customer contracts that we are awarded, it is
possible for contract values and actual costs to vary from estimates previously made, which may result in reductions or
reversals of previously recorded revenues and profits.
Among the other areas currently requiring significant estimates by our management are the following:
•
•
•
•
the assessment of the value of goodwill and recoverability of other purchased intangible assets;
the determination of provisions for income taxes, the accounting for uncertain income tax positions and the
establishment of valuation allowances associated with deferred income tax assets;
the determination of the fair value of stock-based incentive awards; and
accruals for estimated liabilities, including warranties and any losses related to legal matters.
Our actual business and financial results could differ from our estimates, which may impact future profits.
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Project backlog amounts may be uncertain indicators of future revenues as project realization may be subject to
unexpected adjustments, delays and cancellations.
At January 31, 2022, the total value of our project backlog for all of our business units was $0.7 billion. Project
cancellations or scope modifications may occur that could reduce the amount of our project backlog and the associated
revenues and profits that we actually earn. Projects that are awarded to us may remain included in our backlog for extended
periods of time as customers experience project delays. Should any unexpected delay, suspension or termination of the
work under such contracts occur, our results of operations may be materially and adversely affected. We cannot guarantee
that revenues projected by us based on our project backlog at January 31, 2022 will be recognized or will result in profitable
operating results.
In March 2018, GPS entered into an EPC services contract to build a 500 MW natural gas-fired power plant in North
Carolina that was added to project backlog at that time. However, due to customer delays including a grid connection
dispute, contract activities have not started and we removed this project from backlog during Fiscal 2021. In May 2019,
GPS entered into the EPC services contract to construct a 625 MW power plant in Harrison County, West Virginia. As a
limited notice-to-proceed with certain preliminary activities was received from the owner of this project at the time, the
value of the contract was added to our project backlog where it remains as of January 31, 2022. However, meaningful
construction activities for the facility are not likely to begin until financial close is achieved which may not occur.
Unsuccessful efforts to develop energy plant projects could result in write-offs and the loss of future business.
The development of a power plant construction project is expensive with a total cost that could approximate or exceed $10
million. The developers of power projects may form single purpose entities, such as limited liability companies, limited
partnerships or joint ventures, to perform the development activities, which are often funded by outside sources. We
periodically see business opportunities where we consider providing financial support to the ownership of a new project,
typically during the development phase, in order to improve the probability of an EPC contract being awarded to us.
In the past, we have been successful in lending funds to single purpose entities formed to develop gas-fired power plants.
Each successful involvement resulted in repayment of the loans to us and, more critically, the award to us of the EPC
contracts for the construction of the corresponding plant. In addition, the completed development efforts resulted in our
receipt of success fees that have exceeded $29.6 million in the aggregate. There can be no assurances that we will benefit
from the successful development of these projects or others that may arise in the future.
Other project development support efforts have not been successful, resulting in the write-off of loan and interest balances,
and the loss of the potential construction project. For example, we supported the development efforts for the 1,740 MW
Chickahominy gas-fired power plant in the Commonwealth of Virginia including funding provided under development
loans and other forms of credit support. Significant development milestones were achieved by the project owner. However,
in February 2022, PJM received notice from FERC accepting PJM’s termination of the interconnection service agreement,
effectively removing the new power plant from PJM’s planning queue, as the project owner has been unable to secure a
fuel-supply for the plant and to obtain the necessary equity financing for the project. The repayment of the development
loans is overdue and our efforts to foreclose on the defaulted debt in an orderly fashion have been rejected. We believe
that the completion of the development of this project has become significantly jeopardized and that it is doubtful that
construction of this power plant will occur. Accordingly, during the fourth quarter of Fiscal 2022, we recorded an
impairment loss related to the capitalized project development costs of this project in the amount of $7.9 million, of which
$2.5 million was attributed to the non-controlling interest. In March 2022, the project owner made a public announcement
of the cancellation of the project.
As discussed above, during Fiscal 2021, we removed the value of a gas-fired power plant EPC services contract from
project backlog. During the fourth quarter of Fiscal 2022, we wrote off the balance of notes receivable and the related
accrued interest, in the total amount of $1.8 million, associated with the project.
The future failure of owners to complete the development of power plants could result in the loss of potential construction
business for us and could result in additional write-off adjustments related to the balance of any project development costs
or amounts lent or credit extended to potential project owners. Further, our failure to obtain the opportunity to support
future power plant development projects and the potential to build the associated power plants could be detrimental to
future growth. Large unfavorable adjustments related to current and/or future developmental projects could have a material
adverse impact on our operating results for a future reporting period.
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Table of Contents Future bonding requirements may adversely affect our ability to compete for new energy plant construction projects.
Our construction contracts frequently require that we obtain payment and performance bonds from surety companies on
behalf of project owners as a condition to the contract award. Historically, we have had a strong bonding capacity.
However, under standard terms, surety companies issue bonds on a project-by-project basis and can decline to issue bonds
at any time or require the posting of additional collateral as a condition to issuing any bonds. Not all of our projects require
bonding. As of January 31, 2022, the estimated value of future work covered by outstanding performance bonds was
approximately $235 million.
Market conditions, changes in our performance or financial position, changes in our surety’s assessment of its own
operating and financial risk or larger future projects could cause our surety company to decline to issue, or substantially
reduce, the amount of bonding available for our work and/or could increase our bonding costs. These actions can be taken
on short notice. If our surety company were to limit or eliminate our access to new bonds, our alternatives would include
seeking bonding capacity from other surety companies, joint venturing with other construction firms, increasing business
with clients that do not require bonds and posting other forms of collateral for project performance, such as letters of credit,
or cash. We may be unable to make alternative arrangements in a timely manner, on acceptable terms, or at all.
Accordingly, if we were to experience an interruption, reduction or other alteration in the availability of bonding capacity,
we may be unable to compete for or work on certain projects.
Our results could be adversely affected by natural disasters or other catastrophic events such as the COVID-19 pandemic.
Natural disasters, such as hurricanes, tornadoes, floods and other adverse weather conditions; or other catastrophic events
such as global pandemics could disrupt our operations, or the operations of one or more of our vendors or customers. In
particular, these types of events could shut-down our construction job sites or fabrication facilities for indefinite periods
of time, break our product supply chain from the impacted region or could cause our customers to delay or cancel projects,
which could impact our ability to operate. To the extent any of these events occur, our operations and financial results
could be adversely affected.
As the COVID-19 outbreak became a global pandemic during Fiscal 2021, it challenged our ability to conduct operations
normally in the U.S., Ireland and the U.K., because sustained labor productivity at our job sites is essential to the
achievement of successful projects. In addition, the Company and certain of our major original equipment manufacturers
source certain supplies, materials and equipment from countries afflicted by the outbreak. Future project interruptions or
delays in the delivery of major power plant components that are related to a renewed spreading of an existing or mutated
strain of the COVID-19 virus could impact our schedules, thereby affecting our ability to complete our fixed-price contract
projects in accordance with current schedules. We have protections in our contracts with major customers that provide
certain relief that helps to mitigate certain financial risks. However, the effectiveness of these protections may be limited
by factors including the financial strength of the customer.
We are actively attempting to manage the project risks presented by the current pandemic. However, due to the uncertainty
regarding the duration and extent of the global COVID-19 outbreak, the ultimate extent of the operational and financial
impacts on us will depend on how long and how disperse the disruptions unfavorably effect our customers, our supply
chains and our labor forces. As a result, the ultimate impacts of the COVID-19 outbreak on our businesses are not
quantifiable at this time.
The war in the Ukraine may result in adverse effects on our business.
Although the fighting in this war has been limited to the country of Ukraine, the adverse effects of the war are spreading
globally. For example, the concerns about disruptions to the world-wide supply of oil have contributed to the upward
pressure on the market price for a barrel of oil, which temporarily soared past $100 per barrel. In our country, the impact
has driven the average price of gasoline to over $4.00/gallon, and in California the average price of gasoline exceeds
$6.00/gallon. The prolonged interruption of the supply of oil and natural gas by Russia to Western European nations may
result in adverse effects to the economies of those countries. Global supply chains, which have already been disrupted by
the far-reaching effects of the COVID-19 epidemic, may suffer future damage if the Ukrainian war escalates. We observe
that the eventual rebuilding of infrastructure and other facilities within Ukraine may directly challenge the ability of
western European companies to obtain of steel, components for electrical cable and other building supplies.
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Table of Contents It is too early to assess the extent or length of any adverse effects of the war in the Ukraine on our ability to control contract
costs and schedules. Such unfavorable effects may adversely impact our business, particularly the results of operations
that we are currently forecasting for Fiscal 2023.
Risks Related to Our Market
Continued disruption of base residual auction schedules may delay the start of planned power projects.
We have maintained that the delays in new business awards to GPS and the project construction starts of certain previously
awarded projects relate to a variety of factors, especially in the northeast and Mid-Atlantic regions of the U.S. Currently,
we believe that the ability of the owners of otherwise fully developed gas-fired power plant projects to close on equity and
permanent debt financing has been challenged by uncertainty in the capital markets caused by multiple factors including
delayed base residual, or “capacity” auctions. For new power projects, lack of visibility regarding future capacity revenue
streams complicates the search for equity and debt financing considerably. Most of our recently completed and awarded
EPC service contracts relate to the construction of natural gas-fired power plants located within the geographic footprint
of the electric power system operated by PJM. This entity operates a capacity market which is a process to ensure long-
term grid reliability by securing the appropriate amount of power supply resources needed to meet predicted future energy
demands. A capacity auction for a particular delivery year is usually held during the month of May, three years prior to
the actual delivery year.
PJM’s 2022/2023 capacity auction was originally scheduled to be held in May 2019, but was postponed until May 2021
as PJM waited for the approval by the FERC of new capacity market rules governing offered prices. PJM then intended to
hold subsequent auctions on an accelerated basis, approximately every six months, through 2024, so that the regular annual
auction routine could then resume in May 2024. However, the next auction, scheduled for December 2021, was postponed
until January 2022 and then was postponed again until June 2022. The next three capacity auction dates have been pushed
out by 8 to 9 months.
Our commencement of new EPC power plant projects may continue to be delayed until the visibility regarding future
capacity revenue streams is restored by the future announcements of capacity prices in the PJM region.
Low electricity capacity market prices in the U.S. may discourage future investment in new gas-fired power plant
development.
The results for the most recent PJM capacity auction that did occur (posted in May 2021) for the delivery year 2022-2023
included a general clearing price that decreased by more than 60% from the corresponding price for the previous year. It
represents the lowest general clearing price since the 2013/2014 delivery year. If clearing prices for future capacity
auctions, when they occur, resume their fall in the U.S., power plant developers may be discouraged from commencing
the development and construction of new power plants which would adversely impact our business.
If the price of natural gas increases, the demand for our construction services could decline.
The overall growth of our power business has been substantially based on the number of combined cycle gas-fired power
plants built by us, as many coal-fired plants have been shut down. In 2010, coal-fired power plants accounted for about
45% of total electricity generation. For 2021, coal accounted for approximately 22% of net electricity generation. On the
other hand, natural-gas fired power plants provided approximately 38% of the electricity generated by utility-scale power
plants in the U.S. in 2021, representing an increase of 60% from the amount of electrical power generated by natural gas-
fired power plants in 2010, which provided approximately 24% of net electricity generation for 2010. The use of coal as a
power source has been adversely affected significantly by the plentiful supply of inexpensive natural gas that is available
through the combined use of fracturing and horizontal drilling.
However, the share of electricity generation provided by natural gas is particularly reactive in the short term to changing
natural gas prices. Due primarily to an increase in gas prices, the use of natural gas as a source of electricity generation at
utility scale power plants declined by 3% during 2021. On the other hand, the use of coal as an electricity generation source
increased by 16%. Higher than expected natural gas prices, even for just the short term, could have adverse effects on the
ability of independent power producers to obtain construction and permanent financing for new natural gas-fired power
plants.
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Table of Contents Soft demand for electrical power may cause deterioration in our financial outlook.
The recently published government reference-case energy outlook for the U.S. projects average increases to utility-scale
electricity generation of slightly less than 1% per year from 2022 through 2050. For calendar year 2021, the total amount
of electricity generated by utility-scale power plants increased by 2.7% as the U.S. economy recovered from the worst
effects of the COVID-19 pandemic. Any future softness in the demand for electrical power in the U.S. due to any additional
adverse impacts of the COVID-19 outbreak, or any other reason, could result in the delay, curtailment or cancellation of
future gas-fired power plant projects, thus decreasing the overall demand for our EPC services and adversely impacting
the financial outlook for our power industry services business.
Intense global competition for engineering, procurement and construction contracts could reduce our market share.
The competitive landscape in the EPC services market for natural gas-fired power plants has changed significantly over
the last few years. Several significant competitors announced their exit from the market for a variety of reasons. Others
have announced intentions to avoid entering into fixed-price contracts citing the disproportionate financial risks born by
contractors. However, the market remains dynamic, and competitors include multi-billion-dollar companies with
thousands of employees. Competing effectively in our market requires substantial financial resources, the availability of
skilled personnel and equipment when needed and the effective use of technology. Meaningful competition is expected to
continue in the domestic market, and could increase in the Irish and British markets, presenting us with significant
challenges to our achieving strong growth rates and acceptable profit margins. If we are unable to meet these competitive
challenges and to win the awards of new projects that provide desirable margins, we could lose market share to our
competitors, experience overall reductions in future revenues and profits or incur losses.
The continuous rise in renewables could reduce the number of future gas-fired power plant projects.
The net amount of electricity generation in the U.S. provided by utility-scale wind and solar photovoltaic facilities
continues to rise. Over the last two years, the net generation has increased by 34.8%. Together, such power facilities
provided approximately 8.8%, 10.6% and 11.9% of the net amount of electricity generated by utility-scale power facilities
in 2019, 2020 and 2021, respectively. In the 2022 reference case of the Energy Information Administration (“EIA”), net
electricity generation from all renewable power sources is expected to represent over 44% of such generation by 2050.
Impetus for this growth has been provided by various factors including laws and regulations that discourage new fossil-
fuel burning power plants, environmental activism, income tax advantages that promote the growth of wind and solar
power, the decline in the costs of renewable power plant components and power storage, and the increase in the scale of
energy storage capacity. Should the pace of development for renewable energy facilities, including wind and solar power
plants, accelerate at faster rates than projected, the number of future natural gas-fired construction project opportunities
for us may fall, which could adversely affect our future revenues, profits and cash flows.
The failure to obtain utility-scale renewable projects could have adverse effects on our growth.
As indicated above, the pace of renewable utility-scale power plant additions in the U.S. is growing. The environmentalist
opposition against coal-fired power generation has expanded meaningfully and effectively to target all fossil fuel energy
projects, including power plants and pipelines, and has evolved into powerful support for renewable energy sources.
Despite our commitment to the construction of state-of-the-art, natural gas-fired power plants as important elements of our
country’s electricity-generation mix in the future, we are directing a meaningful portion of our business development
efforts to winning projects for the erection of utility-scale wind farms and solar fields and for the construction of other
renewable energy projects. If we expect our power industry business to achieve sustained future growth, it is likely that
such growth will depend, in a meaningful way, on our ability to capture a portion of the construction market for renewable
power plants that is significant to us. We have successfully built utility-scale wind and solar farms, biomass fueled power
plants and biodiesel energy facilities in the past and we have renewed the pursuit of renewable energy projects that will
complement our natural gas-fired EPC services projects as a core business development focus going forward.
In May 2021, we announced that GPS entered into an EPC services contract to construct the Maple Hill Solar energy
facility in Pennsylvania. This project will be constructed using over 235,000 photovoltaic modules to generate
approximately 100 MW of electricity.
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Table of Contents Failure to obtain future awards for the construction of renewable energy facilities, in particular the erection of substantial
wind farms and solar-powered utility-scale power projects like the Maple Hill Solar project, could have adverse effects on
our future revenues, profits and cash flows.
Unexpected and adverse changes in the foreign countries in which we operate could result in project disruptions, increased
cost and potential losses.
Our business is also subject to international economic and political conditions that change for reasons which are beyond
our control. Such changes may have unfavorable consequences for us. Operating in the international marketplace, which
for us exists primarily in Ireland and the U.K., may expose us to a number of risks including:
• abrupt changes in domestic and/or foreign government policies, laws, treaties (including those impacting trade),
regulations or leadership;
restrictions on currency movement;
tax or tariff increases;
• embargoes or other trade restrictions, including sanctions;
•
•
• currency exchange rate fluctuations;
• changes in labor conditions and difficulties in staffing and managing international operations; and
• other social, political and economic instability.
Our level of exposure to these risks will vary on each significant project we perform overseas, depending on the location
and the particular stage of the project. To the extent that our international business is affected by unexpected and adverse
foreign economic changes, including trade retaliation from certain countries, we may experience project disruptions and
losses which could significantly reduce our consolidated revenues and profits, or could cause losses reflected at the
consolidated level.
Risks Related to the Regulatory Environment
We are required to comply with environmental laws and regulations that may add unforeseen costs to our business.
Our operations are subject to compliance with federal, state and local environmental laws and regulations, including those
relating to discharges to air, water and land, the handling and disposal of solid and hazardous waste, and the cleanup of
properties affected by hazardous substances. Certain environmental laws impose substantial penalties for non-compliance
and others, such as the federal Comprehensive Environmental Response, Compensation and Liability Act, impose strict,
retroactive, and joint and several liability upon persons responsible for releases of hazardous substances. We continually
evaluate whether we must take additional steps to ensure compliance with environmental laws, however, there can be no
assurance that these requirements will not change and that compliance will not add costs to our projects that could
adversely affect our operating results in the future.
The election of President Biden has resulted in additional regulatory hurdles for fossil-fuel energy facilities.
A significant headwind for future gas-fired power plant developments relates to the policies of President Joseph R. Biden,
Jr., who has proposed to make the electricity production in the U.S. carbon free by 2035 and to put the country on the path
to achieve net zero carbon emissions by 2050. Since he has taken office, President Biden has caused the U.S. to re-join the
Paris climate agreement. He has denied permission for the Keystone Pipeline to cross the U.S.-Canadian border. He has
issued an executive order temporarily suspending new oil and gas leasing on federal lands. One additional element of his
plan is to ban fracking on federal land. However, as about 90% of fracking occurs on state or private lands, the vast
majority of fracking will be unaffected. There may be practical, political and legal hurdles in Mr. Biden’s path, but his
election, in part, does represent an indication that public sentiment against fossil-fuel sourced energy is growing rapidly,
which may create future obstacles for fossil fuel-based energy facility developers to obtain the permits necessary for the
start of construction activities.
Future construction projects may depend on the continuing acceptability of the hydraulic fracturing process in certain
states.
The viability of the gas-fired power plants that we build is based substantially on the availability of inexpensive natural
gas supplies provided through the use of hydraulic fracturing (“fracking”) combined with horizontal drilling techniques.
Certain technological advancements led to the widespread use of fracking and horizontal drilling enabling drillers to reach
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natural gas and oil deposits previously trapped within shale rock formations deep under the earth’s surface. The access to
new oil and gas reserves transformed the oil and gas industry in the U.S. In particular, the new supplies of natural gas
generally lowered the price of natural gas in the U.S. and reduced its volatility, making the operation of natural gas-fired
power plants more economically appealing. However, the process of fracking uses large volumes of highly pressurized
water to break-up the shale rock formations and to free the trapped natural gas and oil. This process is controversial due
to concerns about the disposal of the waste water, the possible contamination of nearby water supplies and the risk of
potential seismic events.
Should future evidence confirm the concerns or should a major contamination or seismic episode occur in the future, the
use of fracking may be suspended, limited, or curtailed by additional state and/or federal authorities. As a result, the supply
of inexpensive natural gas may not be available in the future and the economic viability of gas-fired power plants may be
jeopardized. A reduction in the pace of the construction of new gas-fired power plants would have a significantly adverse
effect on our future operating results.
The inability of power project developers to receive or to avoid delay in receiving the applicable regulatory approvals
relating to energy projects, including new natural gas pipelines, may result in lost or postponed revenues for us.
The commencement and/or execution of the types of projects performed by our power industry services reporting segment
are subject to numerous regulatory permitting processes. Applications for the variety of clean air, water purity and
construction permits may be opposed by individuals or environmental groups, resulting in delays and possible denial of
the permits. There are no assurances that our project owner customers will obtain the necessary permits for these projects,
or that the necessary permits will be obtained in order to allow construction work to proceed as scheduled. Failure to
commence or complete construction work as anticipated could have material adverse impacts on our future revenues,
profits and cash flows.
In particular, the viability of new natural gas-fired power plants depends on the availability of nearby sources of natural
gas for fuel which may require the construction of new pipelines for the delivery of gas to a power plant location. A
planned plant may also depend on the erection of transmission lines for the delivery of the newly generated electricity to
the grid. Concerns about climate change have resulted in increased environmental activism that represents opposition to
the regulatory approval of any fossil-fuel energy project. As a result, approval delays and public opposition to new oil and
gas pipelines have become major potential hurdles for the developers of gas-fired power plants and other fossil fuel
facilities. The slowdown in permitting processes is due, at least in part, to the increase in environmental activism that
garners media attention and fosters public skepticism about new projects. In particular, pipeline projects are delayed by
onsite protest demonstrations, indecision by local officials and lawsuits.
Work stoppages, union negotiations and other labor problems could adversely affect us.
The performance of certain large-scale construction contracts results in the hiring of employees represented by labor
unions. We do make sincere efforts to maintain favorable relationships and conduct good-faith negotiations with union
officials. However, there can be no assurances that such efforts will eliminate the possibilities of unfavorable conflicts in
the future. A lengthy strike or the occurrence of other work disputes, slowdowns or stoppages at any of our current or
future construction project sites could have an adverse effect on us, resulting in cost overruns, schedule delays or even
lawsuits that could be significant. In addition, labor incidents could result in negative publicity for us thereby damaging
our business reputation and perhaps harming our prospects for the receipt of future construction contract awards in certain
locales.
Risks Related to Our Operational Execution
We may experience reduced profits or incur losses under fixed price contracts if costs increase above estimates.
Primarily, our business is performed under long-term, fixed price contracts at prices that reflect our estimates of
corresponding costs and schedules. Inaccuracies in these estimates may lead to cost overruns that may not be paid by our
project owner customers. If we fail to accurately estimate the resources required and time necessary to complete these
types of contracts, or if we fail to complete these contracts within the costs and timeframes to which we have agreed, there
could be material adverse impacts on our actual financial results, the accuracy of forecasted future results, as well as our
business reputation.
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Table of Contents Factors not discussed above that could result in contract cost overruns, project delays or other problems for us may include:
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delays in the scheduled deliveries of machinery and equipment ordered by us or a project owner (i.e., supply
chain disruptions);
unanticipated technical problems, including design or engineering issues;
inadequate project execution tools for recording, tracking, forecasting and controlling future costs and
schedules;
unforeseen increases in the costs of labor, warranties, raw materials, components or equipment, or our failure or
inability to obtain resources when needed;
reliance on historical cost and/or execution data that is not representative of current conditions;
delays or productivity issues caused by weather conditions, or other forces majeure (i.e., pandemics);
incorrect assumptions related to labor productivity, scheduling estimates or future economic conditions,
including the impacts of inflation on fixed-price contracts;
• workmanship deficiencies resulting in delays and costs associated with the performance by us of unanticipated
rework; and
• modifications to projects that create unanticipated costs or delays.
These risks tend to be exacerbated for longer-term contracts because there is increased risk that the circumstances under
which we based our original cost estimates or project schedules will change with a resulting increase in costs or delays in
achieving scheduled milestones. In such events, our financial condition and results of operations could be negatively
impacted. For example, most of our work on the TeesREP project in the U.K. was performed pursuant to a fixed-price
subcontract. The loss incurred on the project by APC and recorded during Fiscal 2020 was approximately $29.5 million.
We try to mitigate these risks by reflecting in our overall cost estimates the reasonable possibility that a number of different
and potentially unfavorable outcomes might occur. There are no assurances that our estimates will be sufficient. If not, our
misjudgments may lead to decreased profits or losses. In some cases, as certain risk scenarios are eliminated or our
concerns regarding certain potential cost and/or schedule issues diminish, we may estimate that the likelihood of an
unforeseen cost overrun has reduced and, accordingly, we may increase the estimated gross margin on the project by
decreasing the remaining overall cost estimate.
If we guarantee the timely completion or the performance of a project, we could incur additional costs to fulfill such
obligations.
In many of our fixed price long-term contracts, we guarantee that we will complete a project by a scheduled date. We
sometimes provide that the project, when completed, will also achieve certain performance standards. Subsequently, we
may fail to complete the project on time or equipment that we install may not meet guaranteed performance standards. In
those cases, we may be held responsible for costs incurred by the customer resulting from any delay or any modification
to the plant made in order to achieve the performance standards, generally in the form of contractually agreed-upon
liquidated damages or obligations to re-perform substandard work. If we are required to pay such costs, the total costs of
the project would likely exceed our original estimate, and we could experience reduced profits or a loss related to the
applicable project.
We may be involved in litigation, liability claims and contract disputes which could reduce our profits and cash flows.
We build large and complex energy plants where design, construction or systems failures can result in substantial injury
or damage to third parties. In addition, the nature of our business results in project owners, subcontractors and vendors
occasionally presenting claims against us for recovery of costs that they incurred in excess of what they expected to incur,
or for which they believe they are not contractually liable. In other cases, project owners may withhold retention and/or
contract payments, for which they believe they do not contractually owe us or based on their interpretation of the contract,
or even terminate the contract. We have been, are, and may be in the future, named as a defendant in legal proceedings
where parties may allege breach of contract and seek recovery for damages or other remedies with respect to our projects
or other matters (see Legal Proceedings in Item 3). These legal matters generally arise in the normal course of our business.
In addition, from time to time, we and/or certain of our current or former directors, officers or employees may be named
as parties to other types of lawsuits.
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Table of Contents Litigation can involve complex factual and legal questions, and proceedings may occur over several years. As a result, it
is typically not possible to predict the likely outcome of legal actions with certainty, but it is likely that any significant
lawsuit or other claim against us that involves lengthy legal maneuvering may have a material adverse effect on us
regardless of the outcome. Any claim that is successfully asserted against us could result in our payment of significant
sums for damages and other losses. Even if we were to prevail, any litigation may be costly and time-consuming, and
would likely divert the attention of our management and key personnel from our business operations over multi-year
periods. Either outcome may result in adverse effects on our financial condition, results of operations, cash flows and our
reputation.
In accordance with customary industry practices, we maintain insurance coverage against some, but not all, potential losses
in order to protect against the risks we face. When it is determined that we have liability, we may not be covered by
insurance or, if covered, the dollar amount of any liability may exceed our policy limits or self-insurance reserves. Further,
we may elect not to carry insurance related to particular risks if our management believes that the cost of available
insurance is excessive relative to the risks presented. In addition, we cannot insure fully against pollution and
environmental risks. Our management liability insurance policies are on a “claims-made” basis covering only claims
actually made during the policy period currently in effect. In addition, even where insurance is maintained for such
exposures, the policies have deductibles resulting in our assuming exposure for a layer of coverage with respect to any
such claims. Any liability not covered by our insurance, in excess of our insurance limits and self-insurance reserves or, if
covered by insurance but subject to a high deductible, could result in a significant loss for us, which claims may reduce
our future profits and cash available for operations.
Our failure to recover adequately on contract variations submitted to project owners could have a material effect on our
financial results.
We may submit contract variations to project owners for additional costs exceeding the contract price or for amounts not
included in the original contract price. For example, in January 2019, we filed a lawsuit against a project owner for breach
of contract and failure to remedy various conditions which negatively affected the schedule and costs associated with the
construction of a gas-fired power plant. This matter was resolved during Fiscal 2022. Variations occur due to matters such
as owner-caused delays or changes from the initial project scope, both of which may result in additional costs. At times,
contract variation submissions can be the subject of lengthy arbitration or litigation proceedings, and it is difficult to
accurately predict when these differences will be fully resolved. When these types of events occur and unresolved matters
are pending, we have used existing liquidity to cover cost overruns pending their resolution. The aggregate amounts of
contract variations included in the transaction prices that were used to determine project-to-date revenues for all of our
projects at January 31, 2022 and 2021 were $7.5 million and $16.6 million, respectively. A failure to promptly recover on
these types of customer submissions could have a negative impact on our liquidity and profitability in the future.
The shortage of skilled craft labor may negatively impact our ability to execute on our long-term construction contracts.
Increased infrastructure spending and general economic expansion may increase the demand for employees with the types
of skills needed for the completion of our projects. There is a risk that our construction project schedules become
unachievable or that labor expenses will increase unexpectedly as a result of a shortage in the supply of skilled personnel
available to us. Labor shortages, productivity decreases or increased labor costs could impair our ability to maintain our
business or grow our revenues. The inability to hire and retain qualified skilled employees in the future, including workers
in the construction crafts, could negatively impact our ability to complete our long-term construction contracts
successfully.
Our dependence upon third parties to complete many of our contracts may adversely affect our performance under current
and future construction contracts.
Certain of the work performed under our energy plant construction contracts is actually performed by third-party
subcontractors we hire. We also rely on third-party manufacturers or suppliers to provide much of the equipment and most
of the materials (such as copper, concrete and steel) needed to complete our construction projects. If we are unable to hire
qualified subcontractors or to find qualified equipment manufacturers or suppliers, our ability to successfully complete a
project could be adversely impacted. If the price we are required to pay for subcontractors or equipment and supplies
exceeds the corresponding amount that we have estimated, we may suffer a loss on the contract. If a supplier, manufacturer
or subcontractor fails to provide supplies, equipment or services as required under a negotiated contract for any reason,
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Table of Contents we may be required to self-perform unexpected work or obtain these supplies, equipment or services on an expedited basis
or at a higher price than anticipated from a substitute source, which could impact contract profitability in an adverse
manner. Unresolved disputes with a subcontractor or supplier regarding the scope of work or performance may escalate,
resulting in arbitration proceedings or legal actions (see “Legal Proceedings” in Item 3 below). Unfavorable outcomes of
such disputes may also impact contract profitability in an adverse manner. In addition, if a subcontractor fails to pay its
subcontractors, suppliers or employees, liens may be placed on our project requiring us to incur the costs of reimbursing
such parties in order to have the liens removed or to commence litigation.
Failure to maintain safe work sites could result in significant losses as we work on projects that are inherently dangerous.
We often work on large-scale and complex projects, sometimes in geographically remote locations. Our project sites can
place our employees and others near large and/or mechanized equipment, high voltage electrical equipment, moving
vehicles, dangerous processes or highly regulated materials, and in challenging environments. Safety is a primary focus of
our business and is critical to our reputation. Often, we are responsible for safety on the project sites where we work. Many
of our customers require that we meet certain safety criteria to be eligible to bid on contracts. Further, regulatory changes
implemented by OSHA or similar government agencies could impose additional costs on us. We maintain programs with
the primary purpose of implementing effective health, safety and environmental procedures throughout our Company.
Currently, our project managers are challenged with maintaining work sites and controlling employee behaviors to comply
with requirements mandated by national, state and local health officials intended to minimize the spread of the COVID-
19 virus. If we fail to implement appropriate safety procedures and/or if our procedures fail, our employees or others may
suffer injuries or illness. The failure to comply with such procedures, client contracts or applicable regulations could
subject us to losses and liability, and adversely impact our ability to complete awarded projects as planned or to obtain
projects in the future. Our OSHA reportable incident rates, weighted by hours worked for all of our subsidiaries, were
0.48, 0.55 and 0.40 for calendars 2021, 2020 and 2019, respectively. Our actual rates were significantly better than the
national averages in our industry (NAICS – 2379) for those years.
Future acquisitions and/or investments may not occur which could limit the growth of our business, and the integration of
acquired companies may not be successful.
Argan is a holding company with current investments in GPS, APC, TRC and SMC. We want to make additional
acquisitions and/or investments that would provide positive cash flow to us and value to our stockholders. However,
additional companies meeting these criteria and that provide products and/or services in growth industries and that are
available for purchase at attractive prices are difficult to find. Discussions with the principal(s) of potential acquisition
targets may be protracted and ultimately terminated for a variety of reasons. Further, due diligence investigations of
attractive target companies may uncover unfavorable data, and the negotiation and consummation of acquisition
agreements may not be successful.
We cannot readily predict the timing or size of any future acquisitions or the capital we will need for these transactions.
However, it is likely that any potential future acquisition or strategic investment transaction would require the use of cash
and/or shares of our common stock as components of the purchase price. Using cash for acquisitions may limit our financial
flexibility and make us more likely to seek additional capital through future debt or equity financings. Our ability to obtain
such additional financing in the future may depend upon prevailing capital market conditions, the strength of our future
operating results and financial condition as well as conditions in our business, and the amount of outside financing sought
by us. These factors may affect our efforts to arrange additional financing on terms that are acceptable to us. Our ability
to use shares of our common stock as future acquisition consideration may be limited by a variety of factors, including the
future market price of shares of our common stock and a potential seller’s assessment of the liquidity of our common
stock. If adequate funds or the use of our common stock are not available to us, or are not available on acceptable terms,
we may not be able to take advantage of desirable acquisitions or other investment opportunities that would benefit our
business. Even if we do complete acquisitions in the future, acquired companies may fail to achieve the results we
anticipate including the expected gross profit percentages.
In general, we keep each of our subsidiary operations separate and distinct. However, we do attempt to integrate certain
aspects to drive synergies and cost reductions. In the future, we may not be able to successfully integrate such acquired
companies with our other operations without substantial costs, delays or other operational or financial problems including:
•
the diversion of management’s attention from other important operational or financial matters;
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•
•
•
the inability to retain or maintain the focus of key personnel of acquired companies;
the discovery of previously unidentified project costs or other liabilities;
unforeseen difficulties encountered in the maintenance of uniform standards, controls, procedures and policies,
including an effective system of internal control over financial reporting; and
impairment losses related to acquired goodwill and other intangible assets.
Circumstances have caused us to record impairment losses related to the goodwill of TRC and APC in prior years in the
aggregate amount of $7.0 million.
Future acquisitions could result in issuances of equity securities that would reduce our stockholders’ ownership interests,
the issuance of sizable amounts of debt and the incurrence of contingent liabilities. Further, we may conclude that the
divestiture of a troubled business will satisfy the best interests of our stockholders. Any divesting transaction could result
in a material loss for us.
In summary, integrating acquired companies may involves unique and significant risks. Our failure to overcome such risks
could materially and adversely affect our business, financial condition and future results of operations, and could cause
damage to our Company’s reputation.
Our failure to protect our management information systems against security breaches could adversely affect our business
and results of operations.
Our computer systems face the threat of unauthorized access, computer hackers, viruses, malicious code, cyberattacks,
phishing and other security incursions and system disruptions, including attempts to improperly access our confidential
and proprietary information as well as the confidential and proprietary information of our customers and other business
partners. A party who circumvents our security measures, or those of our clients, contractors or other vendors, could
misappropriate confidential or proprietary information, improperly manipulate data, or cause damage or interruptions to
systems.
Various privacy and security laws in the US and abroad, including the General Data Protection Regulation (“GDPR”) in
the European Union, require us to protect sensitive and confidential information and data from disclosure and we are bound
by our client and other contracts, as well as our own business practices, to protect confidential and proprietary information
and data (whether it be ours or a third party’s information entrusted to us) from unauthorized disclosure. We believe that
we have deployed industry-accepted security measures and technology to securely maintain confidential and proprietary
information retained within our information systems, including compliance with GDPR specifically at APC. However,
these measures and technology may not adequately prevent unanticipated security breaches. There can be no assurance
that our efforts will prevent these threats. Further, as these security threats continue to evolve, we may be required to
devote additional resources to protect, prevent, detect and respond against such threats. We do believe that our business
represents a low value target for cyberterrorists as we are not a company in the high technology space and we do not
maintain large files of sensitive or confidential personal information. However, we do maintain a cybersecurity insurance
policy to help protect ourselves from various types of losses relating to computer security breaches.
We can report that we are unaware of any other significant security breaches at any of our business locations that occurred
during Fiscal 2022. That does not suggest that we may not be victimized by a meaningful breach in the future. Any
significant future breach of our information security could damage our reputation, result in litigation and/or regulatory
fines and penalties, or have other material adverse effects on our business, financial condition, results of operations or cash
flows.
Should our management information systems become unavailable for any significant period of time, our business could
be harmed.
The efficient operation of our business is dependent on computer hardware and software systems. We are heavily reliant
on computer, information and communications technology and related systems, some of which are hosted by third party
providers, in order to operate effectively. We may experience system availability disruptions that may or may not occur
as the result of planned procedures. Unplanned interruptions may include natural disasters, power loss, telecommunications
failures, acts of terrorism, computer viruses, physical or electronic break-ins and similar cybersecurity intrusions as
discussed above. Any of these or other events could delay or prevent necessary operations (including the processing of
transactions and the reporting of financial results).
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Table of Contents While we believe that our reasonable safeguards will protect us from serious disruptions in the availability of our
information technology assets, these safeguards may not be sufficient. We may also be required to expend significant
resources to protect against or alleviate damage caused by systems interruptions and delays.
We do evaluate the need to upgrade and/or replace our systems and network infrastructure to protect our computing
environment, to stay current on vendor-supported products, to improve the efficiency of our systems and for other business
reasons. The implementation of new systems and information technology could adversely impact our operations by
imposing substantial capital expenditures, demands on management time and risks of delays or difficulties in transitioning
to new systems. The unavailability of the information systems or the failure of the systems to perform as anticipated for
any reason could disrupt our business and could result in decreased performance and increased overhead costs, causing
our business to suffer. Any significant interruption or failure of our information systems could disrupt the conduct of our
business in a meaningful manner, possibly causing adverse effects on our business, financial condition or results of
operations.
We may be subject to increased corporate taxes in the future.
We are subject to income taxes in the U.S. and foreign jurisdictions. A change in tax laws, treaties or regulations, or their
interpretation, in any country where we operate could result in higher tax rates applied to our pre-tax earnings resulting in
higher tax amounts. Such higher corporate taxes could result from a resurrected Build-Back-Better Act (or subset thereof)
that would likely increase the U.S. corporate tax rate to 25%-28% and perhaps establish a 1% surcharge on corporate stock
buy-backs, or the Global Minimum Tax, a recent global agreement to ensure that certain large corporations pay income
tax at a minimum rate of 15%. Under this scheme, governments could still set whatever corporate tax rate they want, but
if companies pay lower rates in a particular country, their home governments could “top-off” their taxes to the 15%
minimum.
In any event, it is likely that we will pay higher U.S. income taxes going forward due to the impact of the Global Intangible
Low Tax Income (“GILTI”) rate. GILTI is a federal tax provision that determines the amount of the current earnings of
foreign subsidiaries that are included in the computation of the corporate tax of U.S. parent companies. We have avoided
this incremental taxation created by the Tax Cuts and Jobs Act (the “Tax Act”) because our foreign operations have
incurred mostly losses since the enactment of the Tax Act in late 2017. However, GILTI may become meaningfully
unfavorable to us if our operations in Ireland and the U.K. remain profitable in the future.
Certain of our tax positions may be successfully challenged by tax authorities which could result in additional income tax
expense.
Significant judgment is required in order to determine our worldwide provision for income taxes for each quarterly and
annual reporting period. In the ordinary course of our business, there are many transactions and calculations where the
ultimate tax determination is uncertain. Our tax estimates and tax positions could be materially affected by many factors
including the final outcome of tax audits and related litigation, the introduction of new tax accounting standards,
legislation, regulations and related interpretations, our global mix of earnings, the realization of deferred tax assets,
changes in uncertain tax positions and changes in our tax strategies.
The results of current or future income tax return examinations could result in unfavorable adjustments to the amounts of
income taxes previously recorded and/or paid. Any such future event or determination related to income taxes could have
a material impact on our net earnings and cash flows from operations.
The Internal Revenue Service (the “IRS”) has issued its revenue agents review reports related to the examination of our
amended consolidated federal income tax returns for Fiscal 2016 and Fiscal 2017, and our consolidated federal income tax
return for Fiscal 2018.
During Fiscal 2019, we completed a detailed review of the activities of our engineering staff on major EPC services
projects in order to identify and quantify the amounts of estimated research and development tax credits that were available
to reduce prior year income taxes. This study focused on project costs incurred during the three-year period ended January
31, 2018. Based on the detailed review, we identified and estimated significant amounts of income tax benefits that were
not previously recognized in our operating results for any prior year reporting period.
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Table of Contents As a result, we recorded an income tax benefit in the net amount of $16.6 million related to the research and development
tax credits during Fiscal 2019, which was subsequently reduced by $0.4 million. The research and development tax credits
were included in amendments to our consolidated federal income tax returns for Fiscal 2016 and Fiscal 2017, that were
filed in January 2019, and our consolidated federal income tax return for Fiscal 2018, that was filed in November 2018.
We have received reports from the IRS that documents its understanding of the facts, attempts to summarize our arguments
in support of the claims and states its position which disagrees with our treatment of a substantial amount of the costs that
support the research and development tax credit claims reflected in our amended tax returns for Fiscal 2016 and Fiscal
2017, and our tax return for Fiscal 2018. After a careful review of the reports, we have concluded that our arguments are
sound and that the reports do not present any new facts relating to the issues or make any new arguments that would cause
us to make any adjustments to our accounting for the research and development tax credit claims as of January 31, 2022
or 2021. We have formally protested the findings of the IRS examiner and intend to pursue our income tax position with
the IRS through the established appeals process.
We have evaluated our income tax positions using the more-likely-than-not threshold in order to determine the amount of
benefits to be recognized in the consolidated financial statements. We do not anticipate any significant changes to the net
amount of the income tax benefits recorded for research and development tax credits claimed for Fiscal 2016 through
Fiscal 2018. However, if negotiations with the IRS or legal decisions cause us to believe that our previously recognized
tax positions no longer meet the more-likely-than-not threshold, the related benefit amounts will be derecognized in the
first financial reporting period in which that threshold is no longer met, which could materially and adversely affect our
future financial condition and operating results.
We could be adversely affected by violations of the Foreign Corrupt Practices Act and similar anti-bribery laws.
The U.S. Foreign Corrupt Practices Act, the U.K. Bribery Act of 2010 and similar anti-bribery laws in other jurisdictions
generally prohibit companies and their intermediaries from making improper payments to officials or others for the purpose
of obtaining or retaining business. While we believe that our policies and oversight in this area are strong, we cannot
provide assurances that our internal controls and procedures always will protect us from the possible reckless or criminal
acts committed by our employees or others. If we are found to be liable for anti-bribery law violations (either due to our
own acts or our inadvertence, or due to the acts or inadvertence of others including our partners, subcontractors or
suppliers), we could suffer from criminal or civil penalties or other sanctions, including contract cancellations or
debarment, and damage to our reputation, any of which could have a material adverse effect on our business. Litigation or
investigations relating to alleged or suspected violations of anti-bribery laws, even if such litigation or investigations
demonstrate ultimately that we did not violate anti-bribery laws, could be costly and could divert management’s attention
away from other aspects of our business.
Our continued success requires us to retain and hire talented personnel.
Undoubtedly, unforeseen future changes in our management will occur. Therefore, we cannot be certain that any key
executive or manager will continue in such capacity while performing at a high level for any particular period of time, nor
can we be certain that events will permit us to complete smooth management transitions should they occur. Our ability to
operate productively and profitably, particularly in the power industry, is dependent on our ability to attract, employ, retain
and train skilled personnel necessary to meet our future requirements. We cannot be certain that we will be able to maintain
experienced management teams and adequately skilled groups of employees necessary to execute our long-term
construction contracts successfully and to support our future growth strategy. The loss of key personnel, the inability to
complete management transitions without significant loss of effectiveness, or the inability to hire and retain qualified
employees in the future could negatively impact our ability to manage our business in the future.
Risks Related to an Investment in Our Securities
Our acquisition strategy may result in dilution to our stockholders.
We may make future acquisitions of other businesses that require the use of cash and issuances of common stock. To the
extent that we intend to use cash for any acquisition, we may be required to raise additional equity and/or obtain debt
financing. Equity financing may result in dilution for our then current stockholders. Stock issuances and financing, if
obtained, may not be on terms favorable to us and could result in substantial dilution to our stockholders at the time(s) of
these transactions.
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Table of Contents Future stock option exercises and restricted stock issuances will dilute the ownership of the Company’s current
stockholders.
As of January 31, 2022, the closing market price for a share of our common stock was $37.15. The average of the monthly
closing prices for our common stock for Fiscal 2022 was $45.70 per share. During Fiscal 2022, the exercise of stock
options by our employees and directors resulted in the issuance of 42,000 shares of our common stock at a weighted
average purchase price of $34.01 per share. As of January 31, 2022, there were outstanding options to purchase 1,404,901
shares of our common stock at a weighted average exercise price of $44.35 per share, including 286,001 shares related to
in-the-money exercisable stock options with a weighted average exercise price of $30.79 per share. Future exercises of
options to purchase shares of common stock at prices below prevailing market prices will result in ownership dilution for
current stockholders.
Further, since April 2019, we have awarded performance-based and time-based restricted stock units to executives and
other key employees covering up to an aggregate of 222,250 shares of common stock plus a number of shares to be
determined based on the amount of cash dividends deemed paid on shares earned pursuant to the awards. The issuance of
common stock earned pursuant to performance based restricted stock units will depend primarily on the total shareholder
return performance of our common stock measured against the performance of peer-group of common stocks over three-
year periods. The three-year period related to the earliest set of awards covering up to 36,000 shares ends in April 2022.
The outstanding time-based restricted stock units cover 82,250 shares of our common stock; these awards will fully vest
in 2024. The number of shares of our common stock that will ultimately be issued in connection with the restricted stock
unit awards is not known. Any issuance will result in the dilution of the stock ownership of current stockholders.
Our officers, directors and certain unaffiliated stockholders have substantial control over the Company.
As of January 31, 2022, our executive officers and directors as a group owned approximately 9.5% of our voting shares
including an aggregate of 852,990 shares of common stock that may be purchased upon the exercise of stock options held
by our executive officers and directors (and deemed exercisable at January 31, 2022), a total of 349,895 shares of common
stock beneficially owned by Rainer H. Bosselmann (our chairman of the board and chief executive officer) and a total of
170,000 shares beneficially owned by William F. Griffin, (a co-founder of GPS and member of our board of directors).
An additional 1.8% of the outstanding shares are controlled by Allen & Company entities (“Allen”). One of our
independent directors is an officer of Allen. In addition, three (3) other stockholders owned approximately 25.9% of our
shares in total as of December 31, 2021. These groups of stockholders may have significant influence over corporate
actions such as the election of directors, amendments to our certificate of incorporation, the consummation of any merger,
the sale of all or substantially all of our assets or other actions requiring stockholder approval.
We may not pay cash dividends in the future.
Our board of directors evaluates our ongoing operational and financial performance in order to determine what role
strategically aligned dividends should play in creating shareholder value. Starting in Fiscal 2019, we have paid regular
quarterly cash dividends in the amount of $0.25 per share of common stock. We also made special cash dividend payments
in the amount of $1.00 per share of common stock in July 2020 and December 2020, and we paid regular and special cash
dividends during earlier years.
There can be no assurance that the evaluations of our board of directors will result in the payment of regular or special
cash dividends in the future.
We may discontinue the repurchase of our common stock in the future.
We began to repurchase shares of our common stock on the open market in November 2021. By January 31, 2022, we
repurchased 527,752 shares at an aggregate price of approximately $20.4 million, or $38.60 per share. Since year-end, we
have continued to make open market purchases pursuant to the approvals of our board of directors. Such approvals, which
permits privately negotiated transactions as well as open market purchases, increased the size of our share repurchase
program from $25 million to $75 million and extended the buy-back authorization until January 2024. We can provide no
guarantee that we will continue to make common stock repurchases up to the approved amount of $75 million.
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Table of Contents As our common stock is thinly traded at times, the stock price may be volatile and investors may have difficulty disposing
of their investments at prevailing market prices.
Our common stock is listed for trading on the NYSE stock exchange and trades under the symbol AGX. Despite the listing
on this national stock exchange, our common stock may trade thinly and sporadically at times and no assurances can be
given that a larger market will ever develop, or if developed, that it will be maintained.
Provisions of our certificate of incorporation and Delaware law could deter takeover attempts.
Provisions of our certificate of incorporation and Delaware law could delay, prevent, or make more difficult a merger,
tender offer or proxy contest involving us. Among other things, our board of directors may issue up to 500,000 shares of
our preferred stock and may determine the price, rights, preferences, privileges and restrictions, including voting and
conversion rights, of these shares. The issuance of preferred stock by us could adversely affect the rights of holders of
common stock by, among other factors, establishing dividend rights, liquidation rights and voting rights that are superior
to the rights of the holders of the common stock. In addition, Delaware law limits transactions between us and persons that
acquire significant amounts of our stock without approval of our board of directors.
ITEM 1B. UNRESOLVED STAFF COMMENTS.
None.
ITEM 2. PROPERTIES.
We occupy our corporate headquarters in Rockville, Maryland, under a lease that expires on May 31, 2024 covering 2,521
square feet of office space.
GPS owns and occupies a three-story office building (23,380 square feet) and the underlying land (1.75 acres), located in
Glastonbury, Connecticut.
TRC leases an 18.77-acre industrial facility (79,774 square feet) in Winterville, North Carolina, under a lease agreement
with a term that expires on April 30, 2022. We expect to extend the term of this lease on commercially acceptable terms
prior to its current expiration date. The facility consists of three fabrication and warehouse buildings totaling 60,356 square
feet, a 9,700 square foot maintenance shop, an office building (7,793 square feet) and a 1,925 square foot modular office
building. The lessor of this arrangement is the founder and current chief executive officer of TRC, John Roberts. Effective
April 1, 2016, based on third party market rent valuations, rent was set at $300,000 per annum payable in equal quarterly
installments. TRC is responsible for normal repairs and maintenance, property taxes, utilities and insurance.
TRC also owns and occupies a one-story industrial fabrication and warehouse facility (90,000 square feet) containing
approximately 5,400 square feet of office space and the underlying land (12.16 acres), which is also located in Winterville,
North Carolina.
APC owns and occupies a warehouse and ancillary offices that total 11,174 square feet in Nenagh, County Tipperary, in
Ireland. The property occupies a site of approximately 1.97 acres and includes secure yards, industrial units and modern
offices. This site has been temporarily designated as the headquarters of APC as it moves the corporate offices from the
Dublin area to Limerick where it plans to purchase an office building to serve as the new corporate headquarters. APC
also leases office space in Derby, England, with a term that runs through August 2022 and an annual rent of approximately
$51,850, and warehouse space in Billingham, England, with a term that runs through January 2025 and an annual rent of
approximately $38,240.
SMC is located in Tracys Landing, Maryland, occupying facilities under a lease that expires in October 2026. Thereafter,
the lease automatically renews for an additional year up to a total of five (5) additional years. The SMC facility includes
approximately five acres of land, a 2,400 square foot maintenance facility and approximately 3,900 square feet of office
space. The rent for the facility, which starts at $7,400 per month, escalates by approximately 3% on October 1, 2024,
October 2026 and October 2029. SMC also uses a nearby fenced-in storage lot and office structure under an operating
lease with a 5-year term that expires on January 31, 2023 and with options to extend for five additional 2-year terms.
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In December 2021, SMC entered into a lease covering the building and adjacent parking and loading areas in Hampton,
Virginia, that serve the operations of SMC’s newly acquired business in that area. The building includes office space
(3,570 square feet) and warehouse space (11,460 square feet) and is sited on a land plot of approximately one (1) acre. The
initial lease term covers five (5) years and includes a tenant option for one additional five (5) year period. The monthly
rent amounts applicable to the initial and extension terms are $9,325 and $9,885, respectively. The facility is owned
indirectly by the former president of LTI.
We consider the Company’s owned and leased properties to be sufficient for continuation of our operations for the
foreseeable future, without significant excess space, except that we intend to acquire office space in the Limerick area of
Ireland for APC as disclosed above. Our operations in the field may require us to occupy additional facilities for project
support, staging or on customer premises or job sites. Accordingly, we may rent local office space, construction offices on
or near job sites, storage yards for equipment and materials and temporary housing units; all under arrangements that are
temporary or short-term in nature. These costs are expensed as incurred and are included substantially in the cost of
revenues.
ITEM 3. LEGAL PROCEEDINGS.
Note 11 to the accompanying consolidated financial statements included in Item 8 of Part II of this 2022 Annual Report
presents a discussion of the legal proceedings that were settled in September 2021. In the normal course of business, we
may have other pending claims and legal proceedings. It is our opinion, based on information available at this time, that
any other current claim or proceeding will not have a material effect on our consolidated financial statements.
PART II
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND
ISSUER PURCHASES OF EQUITY SECURITIES.
Shares of our common stock trade under the symbol AGX on the New York Stock Exchange (the “NYSE”). As of April
11, 2022, we had approximately 58 stockholders of record.
Dividends
Since Fiscal 2019, our board of directors has declared and we have paid regular quarterly cash dividends of $0.25 per
share, totaling $1.00 per share for each year. During Fiscal 2021, our board of directors also declared and we paid two
special cash dividends of $1.00 per share each, and we issued a statement expressing confidence in the future of our
business and satisfaction with the opportunity to return a portion of our accumulated earnings to the stockholders during a
year marked by the challenges presented by the COVID-19 pandemic. The statement cited our strong balance sheet with
significant liquidity and no debt and the increased ramp-up of construction on the Guernsey Power Station, the largest
project in our history.
Each quarter, our board of directors evaluates the Company’s ongoing operational and financial performance in
determining the amount of the regular dividend and any special dividend. There can be no assurance that these evaluations
will result in the payment of cash dividends in the future.
Share Repurchase Program
On January 24, 2022, we made a filing on Current Report Form 8-K announcing that our board of directors authorized an
increase in our existing share repurchase program, from $25 million to $50 million, to acquire shares of the Company’s
common stock (the “Repurchase Plan”). The repurchases may occur in the open market or through investment banking
institutions, privately-negotiated transactions, or direct purchases, and the timing and amount of stock repurchased will
depend on market and business conditions, applicable legal and credit requirements and other corporate considerations.
In accordance with the SEC’s Rule 10b5-1 and pursuant to the Repurchase Plan, we have allowed, and may in the future
allow, the repurchase of our common stock during trading blackout periods by an investment banking firm or other
institution agent acting on our behalf pursuant to predetermined parameters.
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The following table provides information regarding common stock repurchases during Fiscal 2022 (dollars in thousands,
except per share data).
Period
November 1 - 30, 2021
December 1 - 31, 2021
January 1 - 31, 2022
Total
Total Number of
Shares Repurchased
Average Price Per
Share Paid
Publicly Announced
Plans or Programs
Be Purchased Under the
Plans or Programs
31,430 $
280,851 $
215,471 $
527,752 $
39.68
38.09
39.12
38.60
31,430 $
280,851 $
215,471 $
527,752
23,753
13,056
29,628
Total Number of
Approximate Dollar
Shares Purchased as Part of Value of Shares that May Yet
Subsequent to January 31, 2022, we continued to repurchase shares of our common stock pursuant to the Repurchase Plan
through April 8, 2022. As of April 8, 2022, we had repurchased 442,079 shares since year-end, all on the open market, for
an aggregate price of approximately $17.1 million, or $38.69 per share.
On April 13, 2022, we made a filing on Current Report Form 8-K announcing an additional authorized increase in our
share Repurchase Plan, from $50 million to $75 million.
Common Stock Price Performance Graph
The graph presented below compares the percentage change in the cumulative total stockholder return on our common
stock for the last five years with the S&P 500, a broad market index, and the Dow Jones US Heavy Construction TSM
Index, a group index of companies where their focus is limited primarily to heavy civil construction. The returns are
calculated assuming that an investment with a value of $100 was made in our common stock and in each index at January
31, 2017, and that all dividends were reinvested in additional shares of common stock. The graph lines merely connect the
measuring dates and do not reflect fluctuations between those dates. The stock performance shown on the graph is not
intended to be indicative of future stock performance.
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Table of Contents
COMPARISON OF 5 YEAR CUMULATIVE TOTAL RETURN*
Among Argan, Inc., the S&P 500 Index
and the Dow Jones US Heavy Construction TSM Index
$250
$200
$150
$100
$50
$0 ~-----~------~------~-----~------~
1/17
1/18
1/19
1/20
1/21
1/22
-Argan,
Inc.
........,._S&P 500
-oow
Jones US Heavy Construction lSM
'$100 invested on 1/31/17 in stock or index, including reinvestment of dividends.
Fiscal year ending January 31.
Copyright© 2022 Standard & Poor's, a division of S&P Global. All rights reserved.
Copyright© 2022 S&P Dow Jones Indices LLC, a division of S&P Global. All rights reserved.
Argan, Inc.
S&P 500
Dow Jones US Heavy Civil Construction TSM
Equity Compensation Plan Information
Years Ended January 31,
2017
100.00
100.00
100.00
2018
60.01
126.41
109.52
2019
59.59
123.48
86.02
2020
60.84
150.26
99.16
2021
66.80
176.18
127.26
2022
58.71
217.21
159.02
In June 2011, the stockholders approved the adoption of the Argan, Inc. 2011 Stock Plan (the “2011 Plan”) including
500,000 shares of our common stock reserved for issuance thereunder. The stockholders approved a succession of
amendments to the 2011 Plan, a ten-year plan, in subsequent years increasing the number of shares of common stock
reserved for issuance thereunder to 2,750,000. On June 23, 2020, our stockholders approved the adoption of the Argan,
Inc. 2020 Stock Plan (the “2020 Plan”), and the allocation of 500,000 shares of the Company’s common stock for issuance
thereunder. The Company’s board of directors may make share-based awards under the 2020 Plan to officers, directors
and key employees. The 2020 Plan succeeds the 2011 Stock Plan as our authority to make awards pursuant to the 2011
Plan expired in July 2021. The features of the 2020 Plan are similar to those included in the 2011 Plan. Together, the 2020
Plan and the 2011 Plan are hereinafter referred to as the “Stock Plans.”
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Awards under the 2020 Plan may include nonqualified stock options, incentive stock options, and restricted or unrestricted
stock. The specific provisions for each award are documented in a written agreement between the Company and the
awardee. All stock options awarded under the 2020 Plan shall have an exercise price per share at least equal to the common
stock’s market value on the date of grant. Stock options shall have terms no longer than ten years. Typically, stock options
are awarded with one-third of each stock option vesting on each of the first three anniversaries of the corresponding award
date.
The following table sets forth certain information, as of January 31, 2022, concerning securities authorized for issuance
under options to purchase our common stock.
Number of Securities
Issuable under Outstanding
Options
Weighted Average Exercise Number of Securities
Price of Outstanding
Options
Remaining Available for
Future Awards (1)
Equity Compensation Plans Approved by the
Stockholders (2)
Equity Compensation Plans Not Approved by
the Stockholders
Totals
1,404,901 $
—
1,404,901 $
44.35
—
44.35
407,250
—
407,250
(1) Represents the number of shares of common stock reserved for future stock awards.
(2) Approved plans include the Company’s Stock Plans.
The number of issuable shares of our common stock under outstanding stock options presented in the chart above does not
include 222,250 shares of our common stock covered by awards of restricted stock units made to members of our board
of directors, our CEO, our CFO and other key employees since April 2019 pursuant to the terms of the Stock Plans. See
Note 12 to the accompanying consolidated financial statements included in Item 8 of Part II of this 2022 Annual Report
for a description of the restricted stock units including the various vesting terms related to the awards.
Unregistered Sales of Equity Securities and Use of Proceeds
None.
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS.
The following discussion summarizes the financial position of Argan, Inc. and its subsidiaries as of January 31, 2022, and
the results of their operations for Fiscal 2022 and Fiscal 2021, and should be read in conjunction with the consolidated
financial statements and notes thereto included elsewhere in Item 8 of this 2022 Annual Report.
Please see “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations,” in the
Company’s Annual Report on Form 10-K for the year ended January 31, 2021, that was filed with the SEC on April 14,
2021, for a discussion of financial trends, variance drivers and other significant matters for Fiscal 2021 as compared to
Fiscal 2020.
Cautionary Statement Regarding Forward Looking Statements
The Private Securities Litigation Reform Act of 1995 provides a “safe harbor” for certain forward-looking statements. We
have made statements in this Item 2 and elsewhere in this 2022 Annual Report that may constitute “forward-looking
statements.” The words “believe,” “expect,” “anticipate,” “plan,” “intend,” “estimate,” “foresee,” “should,” “would,”
“could,” or other similar expressions are intended to identify forward-looking statements. Our forward-looking statements,
including those relating to the potential effects of the COVID-19 pandemic on our business, financial position and results
of operations, are based on our current expectations and beliefs concerning future developments and their potential effects
on us. There can be no assurance that future developments affecting us will be those that we anticipate. All comments
concerning our expectations for future revenues and operating results are based on our forecasts for existing operations
and do not include the potential impact of any future acquisitions.
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Our forward-looking statements, by their nature, involve significant risks and uncertainties (some of which are beyond our
control) and assumptions. They are subject to change based upon various factors including, but not limited to, the risks
and uncertainties described in Item 1A of this 2022 Annual Report. Should one or more of these risks or uncertainties
materialize, or should any of our assumptions prove to be incorrect, actual results may vary in material respects from those
projected in the forward-looking statements. We undertake no obligation to publicly update or revise any forward-looking
statements, whether as a result of new information, future events or otherwise.
Business Description
Argan is a holding company that conducts operations through its wholly-owned subsidiaries, GPS, APC, SMC and TRC.
Through GPS and APC, we provide a full range of engineering, procurement, construction, commissioning, operations
management, maintenance, development, technical and consulting services to the power generation market, including the
renewable energy sector, for a wide range of customers, including independent power project owners, public utilities,
equipment suppliers and global energy plant construction firms. GPS and APC represent our power industry services
reportable segment. Through TRC, the industrial fabrication and field services reportable segment provides on-site services
that support maintenance turnarounds, shutdowns and emergency mobilizations for industrial plants primarily located in
the southeast region of the U.S. and that are based on its expertise in producing, delivering and installing fabricated steel
components such as piping systems and pressure vessels. Through SMC Infrastructure Solutions, the telecommunications
infrastructure services segment provides project management, construction, installation and maintenance services to
commercial, local government and federal government customers primarily in the Mid-Atlantic region of the U.S.
We intend to make additional opportunistic acquisitions and/or investments by identifying companies with significant
potential for profitable growth and realizable synergies with one or more of our existing businesses. However, we may
have more than one industrial focus depending on the opportunity. We expect that acquired companies will be maintained
in separate subsidiaries that will be operated in a manner that best provides cash flows for the Company and value for our
stockholders.
Overview
Operating Results
Consolidated revenues for Fiscal 2022 were $509.4 million, which represented an increase of $117.1 million, or 29.9%,
from consolidated revenues of $392.2 million reported for Fiscal 2021.
The revenues of the power industry services segment increased by $78.7 million to $398.1 million for Fiscal 2022 from
$319.4 million reported for Fiscal 2021. The revenues of this reportable segment of our business represented 78.2% of
consolidated revenues for Fiscal 2022. For Fiscal 2021, the percentage share of consolidated revenues represented by this
reportable segment was 81.4%. The industrial services business of TRC reported revenues of $97.9 million for Fiscal
2022. This amount represented an increase of $32.6 million, or 49.9%, from revenues of $65.3 million reported by TRC
for Fiscal 2021. Revenues provided by this reportable business segment represented 19.2% and 16.6% of corresponding
consolidated revenues for Fiscal 2022 and Fiscal 2021, respectively. The telecommunications infrastructure services
business increased its revenues to $13.4 million for Fiscal 2022 from revenues of $7.6 million for Fiscal 2021, representing
an increase of 76.4%. Revenues provided by this reportable segment represented 2.6% and 1.9% of corresponding
consolidated revenues for Fiscal 2022 and Fiscal 2021, respectively.
Consolidated gross profit improved by $37.6 million, or 60.5%, to $99.7 million for Fiscal 2022, or 19.6% of the
corresponding consolidated revenues. The amount of consolidated gross profit reported for Fiscal 2021 was $62.1 million,
or 15.8% of the corresponding consolidated revenues. The year-over-year improvement reflected primarily the favorable
impacts of the higher consolidated revenues and favorable gross profit contributions from all three reportable business
segments.
Selling, general and administrative expenses for Fiscal 2022 and Fiscal 2021 were $47.3 million, or 9.3% of corresponding
consolidated revenues, and $39.0 million, or 10.0% of corresponding consolidated revenues, respectively. Additionally,
due to the unsuccessful project development efforts by our VIE, we recorded an impairment loss related to the capitalized
project development costs of this project in the amount of $7.9 million during Fiscal 2022, of which $2.5 million was
attributed to the non-controlling interest.
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Table of Contents Due primarily to the consolidated pre-tax book income reported for Fiscal 2022 in the amount of $47.1 million, we reported
income tax expense in the amount of $11.4 million for the year. For Fiscal 2021, we reported consolidated pre-tax book
income of $24.9 million and recorded income tax expense in the amount of $1.1 million, which amount is net of a $4.4
million net operating loss (“NOL”) carryback benefit.
For Fiscal 2022, our improved overall operating performance resulted in net income attributable to our stockholders in the
amount of $38.2 million, or $2.40 per diluted share. For Fiscal 2021, we reported net income attributable to our
stockholders in the amount of $23.9 million, or $1.51 per diluted share.
The primary drivers of our improved operating performance for Fiscal 2022 were the increased revenues and steady gross
margin contribution associated with the construction of the Guernsey Power Station, the new revenues and gross profit
contributions of the solar facility EPC services project at Maple Hill, and the strong results of TRC and APC which both
reported increased revenues and gross profit amounts for Fiscal 2022.
Engineering, Procurement and Construction Service Contracts
At January 31, 2022, our consolidated project backlog amount of $0.7 billion consisted substantially of the projects of the
power industry services reporting segment. The comparable backlog amount as of January 31, 2021 was $0.8 billion. Our
reported amount of project backlog at a point in time represents the total value of projects awarded to us that we consider
to be firm as of that date less the amounts of revenues recognized to date on the corresponding projects (project backlog
is larger than the value of remaining unsatisfied performance obligations, or RUPO, on active contracts; see Note 4 to the
accompanying consolidated financial statements).
Typically, we include the total value of EPC services and other major construction contracts in project backlog when we
receive a corresponding notice to proceed from the project owner. However, we may include the value of an EPC services
contract prior to the receipt of a notice to proceed if we believe that it is probable that the project will commence within a
reasonable timeframe, among other factors. Projects that are awarded to us may remain included in our backlog for
extended periods of time as customers experience project delays. However, cancellations or reductions may occur that
would reduce project backlog and that could adversely affect our expected future revenues.
A meaningful amount of the project backlog amount at January 31, 2022 was represented by the Guernsey Power Station,
the largest single-phase, gas-fired, power plant construction project in the U.S. Substantial completion of this project is
currently scheduled to occur during the second half of Fiscal 2023.
Despite our commitment to the construction of state-of-the-art, natural gas-fired power plants as important elements of our
country’s electricity-generation mix in the future, we have been directing certain business development efforts to winning
projects for the erection of utility-scale wind farms and solar fields and for the construction of hydrogen-based and other
renewable energy projects. We have successfully completed these types of projects in the past and we have renewed efforts
to obtain new work in the renewable power sector that will complement our natural gas-fired EPC services projects going
forward. These efforts led to our announcement in May 2021 that GPS entered into an EPC services contract with CPV
Maple Hill Solar, LLC, an affiliate of CPV, to construct the Maple Hill Solar facility, which we believe will be among the
largest solar-powered energy plants in Pennsylvania. Project activities were begun by GPS immediately. Project
completion is currently scheduled to occur during the second half of Fiscal 2023. The unique Maple Hill Solar project,
which is located in Cambria County, will be constructed using over 235,000 photovoltaic modules to generate
approximately 100 MW of electrical power.
The business development efforts conducted by our APC operations have resulted in a significant increase in the project
backlog of this business. The most significant award occurred in October 2021 as APC entered into an engineering and
construction services contract with EPUKI London, U.K., to construct a 2 x 330 MW natural gas-fired power plant in
Carrickfergus that is near Belfast, Northern Ireland, and that will replace coal-fired units at the site. The facility is being
developed by EPNI Energy Limited. A notice to proceed was received and project activities have commenced. The overall
completion of this project is expected to occur in the latter half of Fiscal 2024.
For Fiscal 2022, meaningful amounts of revenues and gross profit were contributed by the U.K. operations of APC that
have completed the installation of a synchronized condenser for the combined cycle, gas-fired, power plant located at the
Isle of Grain site in the Kent region of the U.K.
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The U.K. operating unit of APC also completed its subcontracted construction efforts consisting primarily of the
mechanical installation of the boiler for TeesREP. With a power rating of 299 MW, TeesREP is one of the largest bio-
mass-fueled power stations in the world that will burn primarily wood pellets in order to generate electricity sufficient to
power 600,000 homes.
The management of APC also grew its Irish operations during Fiscal 2022. For example, APC is performing the design
and build of a dedicated power plant within a major data center. The size and configuration of the facility, consisting of
up to nine (9) gas-fired turbines, is a first-of-a-kind facility within the Irish data center market. They are also completing
construction activities for a major computer chip manufacturer. Both of these Irish projects are located near Dublin.
As announced in Fiscal 2019, GPS entered into an EPC services contract to construct the Chickahominy Power Station, a
1,740 MW natural gas-fired power plant, in Charles City County, Virginia. We did not include the value of this contract
in our project backlog. We provided financing through notes receivable from the consolidated VIE that was established
by the project owner and that was dedicated to the development efforts. We also provided technical support to the project.
Significant development milestones were achieved by the project owner. However, a planned gas pipeline expansion that
the project owner believed would supply natural gas to the power plant was rejected by Virginia’s State Corporation
Commission during Fiscal 2022, which led to cancellation by PJM of its interconnection service agreement with the project
based on alleged failures of the project to meet required milestones. In February 2022, PJM received notice from FERC
accepting PJM’s termination of the service agreement which effectively removed the Chickahominy Power Station from
PJM’s planning queue.
In summary, the project owner was unable to secure an alternative fuel-supply for the plant and the project lost its
interconnection service commitment with PJM. Therefore, the project owner was unable to obtain the necessary equity
financing for the project and we ceased providing project development funding. We concluded that the completion of the
development of this project is significantly jeopardized and that it is doubtful that construction of this power plant will
occur. Accordingly, consistent with the disclosure included in the Current Report on Form 8-K that we filed on January
24, 2022, we recorded an impairment loss during the fourth quarter of Fiscal 2022 related to the capitalized project
development costs of this project in the amount of $7.9 million, of which $2.5 million was attributed to the non-controlling
interest. In March 2022, the project owner issued a public statement that the project was cancelled.
Market Outlook
The overall growth of our power business has been substantially based on the number of combined cycle gas-fired power
plants built by us, as many coal-fired plants have been shut down. In 2010, coal-fired power plants accounted for about
45% of total electricity generation. For 2021, coal accounted for approximately 22% of net electricity generation. On the
other hand, natural-gas fired power plants provided approximately 38% of the electricity generated by utility-scale power
plants in the U.S. in 2021, representing an increase of 60% from the amount of electrical power generated by natural gas-
fired power plants in 2010, which provided approximately 24% of net electricity generation for 2010. Undoubtedly, the
long-term historic decline in the use of coal as a power source in the U.S. was caused, to a significant extent, by the
plentiful supply of domestic and generally inexpensive natural gas which made it the fuel of choice for power plant
developers over this period.
In the reference case of its Annual Energy Outlook 2022, the EIA projects average increases to utility-scale electricity
generation in the U.S. of slightly less than 1% per year from 2022 through 2050. The shift from coal to natural gas as a
power plant energy source in the U.S. is expected to continue as the EIA projects that coal-fired generation will decline
by 45% from 2022 through 2050, and will represent only 11% of the net electricity generation mix by the end of this
period. The net electricity generation from natural gas-fired power plants is projected to increase by 17% in the U.S. by
2050.
The pace of the historic increase in the preference for natural gas as an electricity generating fuel source was energized, in
part, by environmental activism and restrictive regulations targeting coal-fired power plants. Now, the environmentalist
opposition against coal-fired power generation has expanded meaningfully to target all fossil fuel energy projects,
including power plants and pipelines, and has evolved into powerful support for renewable energy sources.
Protests against fossil-fuel related energy projects continue to garner media attention and stir public skepticism about new
projects resulting in delays due to onsite protest demonstrations, indecision by local officials and lawsuits. During Fiscal
2021, a natural gas-fired power plant that we had been awarded the EPC services contract to build, the Brooke County
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Table of Contents Table of Contents The U.K. operating unit of APC also completed its subcontracted construction efforts consisting primarily of the
mechanical installation of the boiler for TeesREP. With a power rating of 299 MW, TeesREP is one of the largest bio-
mass-fueled power stations in the world that will burn primarily wood pellets in order to generate electricity sufficient to
power 600,000 homes.
The management of APC also grew its Irish operations during Fiscal 2022. For example, APC is performing the design
and build of a dedicated power plant within a major data center. The size and configuration of the facility, consisting of
up to nine (9) gas-fired turbines, is a first-of-a-kind facility within the Irish data center market. They are also completing
construction activities for a major computer chip manufacturer. Both of these Irish projects are located near Dublin.
As announced in Fiscal 2019, GPS entered into an EPC services contract to construct the Chickahominy Power Station, a
1,740 MW natural gas-fired power plant, in Charles City County, Virginia. We did not include the value of this contract
in our project backlog. We provided financing through notes receivable from the consolidated VIE that was established
by the project owner and that was dedicated to the development efforts. We also provided technical support to the project.
Significant development milestones were achieved by the project owner. However, a planned gas pipeline expansion that
the project owner believed would supply natural gas to the power plant was rejected by Virginia’s State Corporation
Commission during Fiscal 2022, which led to cancellation by PJM of its interconnection service agreement with the project
based on alleged failures of the project to meet required milestones. In February 2022, PJM received notice from FERC
accepting PJM’s termination of the service agreement which effectively removed the Chickahominy Power Station from
PJM’s planning queue.
In summary, the project owner was unable to secure an alternative fuel-supply for the plant and the project lost its
interconnection service commitment with PJM. Therefore, the project owner was unable to obtain the necessary equity
financing for the project and we ceased providing project development funding. We concluded that the completion of the
development of this project is significantly jeopardized and that it is doubtful that construction of this power plant will
occur. Accordingly, consistent with the disclosure included in the Current Report on Form 8-K that we filed on January
24, 2022, we recorded an impairment loss during the fourth quarter of Fiscal 2022 related to the capitalized project
development costs of this project in the amount of $7.9 million, of which $2.5 million was attributed to the non-controlling
interest. In March 2022, the project owner issued a public statement that the project was cancelled.
Market Outlook
The overall growth of our power business has been substantially based on the number of combined cycle gas-fired power
plants built by us, as many coal-fired plants have been shut down. In 2010, coal-fired power plants accounted for about
45% of total electricity generation. For 2021, coal accounted for approximately 22% of net electricity generation. On the
other hand, natural-gas fired power plants provided approximately 38% of the electricity generated by utility-scale power
plants in the U.S. in 2021, representing an increase of 60% from the amount of electrical power generated by natural gas-
fired power plants in 2010, which provided approximately 24% of net electricity generation for 2010. Undoubtedly, the
long-term historic decline in the use of coal as a power source in the U.S. was caused, to a significant extent, by the
plentiful supply of domestic and generally inexpensive natural gas which made it the fuel of choice for power plant
developers over this period.
In the reference case of its Annual Energy Outlook 2022, the EIA projects average increases to utility-scale electricity
generation in the U.S. of slightly less than 1% per year from 2022 through 2050. The shift from coal to natural gas as a
power plant energy source in the U.S. is expected to continue as the EIA projects that coal-fired generation will decline
by 45% from 2022 through 2050, and will represent only 11% of the net electricity generation mix by the end of this
period. The net electricity generation from natural gas-fired power plants is projected to increase by 17% in the U.S. by
2050.
The pace of the historic increase in the preference for natural gas as an electricity generating fuel source was energized, in
part, by environmental activism and restrictive regulations targeting coal-fired power plants. Now, the environmentalist
opposition against coal-fired power generation has expanded meaningfully to target all fossil fuel energy projects,
including power plants and pipelines, and has evolved into powerful support for renewable energy sources.
Protests against fossil-fuel related energy projects continue to garner media attention and stir public skepticism about new
projects resulting in delays due to onsite protest demonstrations, indecision by local officials and lawsuits. During Fiscal
2021, a natural gas-fired power plant that we had been awarded the EPC services contract to build, the Brooke County
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Table of Contents Power project, was canceled by its developer. Although changing market conditions were cited as important factors in the
cancellation decision and despite strong local support for the project, the opposition by the governor of West Virginia was
likely a factor in the declining enthusiasm for the project. Further, during Fiscal 2021, Dominion Energy and Duke Energy
announced the abandonment of plans to complete the major Atlantic Coast Pipeline, ending a seven-year effort to build a
600-mile natural gas pipeline between West Virginia and eastern North Carolina, citing that the economic viability of the
project was threatened by continuing delays and increasing cost uncertainty after a federal judge issued a ruling preventing
the use of an accelerated construction permitting process. Most recently, as disclosed above, the developer cancelled the
Chickahominy power station project, citing opposition from outside interests and onerous regulations largely advanced by
the renewable energy movement.
In the New England and Mid-Atlantic regions of the U.S., power plant operators are challenged by the requirements of the
Regional Greenhouse Gas Initiative, or “RGGI,” which is a cooperative effort by states in these regions to cap and reduce
power sector carbon dioxide emissions. In addition, various cities, counties and states have adopted clean energy and
carbon-free goals or objectives with achievement expected by a certain future date, typically 10 to 30 years out. These
aspirational goals may increase the risk of a new power plant becoming a stranded asset long before the end of its otherwise
useful economic life, which is a risk that potential equity capital providers may be unwilling to take. The difficulty in
obtaining project equity financing and the other factors identified above, may be adversely impacting the planning and
initial phases for the construction of new natural gas-fired power plants.
Perhaps the most significant uncertainty relates to the policies of the current U.S. Presidential administration. President
Biden proposes to make the electricity production in the U.S. carbon free by 2035 and to put the country on the path to
achieve net zero carbon emissions by 2050. As soon as he was elected, Mr. Biden caused the U.S. to re-join the Paris
Climate Agreement and he cancelled the permit allowing the Keystone XL Pipeline to cross the border from Canada into
the U.S. In addition, Mr. Biden ordered a pause on the U.S. government entering into new oil and natural gas leases on
public lands or offshore waters to the extent possible, the launch of a rigorous review of all existing leasing and permitting
practices related to fossil fuel development on public lands and waters, and the identification of steps that can be taken to
double renewable energy production from offshore wind by 2030. These policy stances have continued during the war in
the Ukraine and the current surge in oil prices as the administration makes appeals to other countries to increase oil
production.
Accordingly, the net amount of electricity generation in the U.S. provided by utility-scale wind and solar photovoltaic
facilities continues to rise. Over the last two years, the net generation has increased by almost 35%. Together, such power
facilities provided approximately 9%, 11% and 12% of the net amount of electricity generated by utility-scale power
facilities in 2019, 2020 and 2021, respectively. In EIA’s 2022 reference case, net electricity generation from all renewable
power sources is expected to increase by more than 161% and represent over 42% of such generation by 2050. Impetus
for this growth is provided by both public concerns about climate change and U.S. government subsidies. Environmental
activism has resulted in the passage of laws and the establishment of regulations that discourage new fossil-fuel burning
power plants and provide income tax advantages that promote the growth of wind and solar power. Declines in the amount
of renewable power plant component and power storage costs and an increase in the scale of energy storage capacity (i.e.,
battery farms) have also occurred.
Over the next few years, EIA projects that new wind and photovoltaic solar capacity will continue to be added to the
utility-scale power fleet in the U.S. at a brisk pace substantially attributable to declining equipment costs and the
availability of valuable tax credits. As these credits decline and then expire early in the next decade as currently scheduled,
the wind capacity additions are expected to slow. Although the special tax incentives related to solar power also expire,
the continuing decline in the cost of solar power equipment is predicted to sustain the growth of photovoltaic solar power
generation facilities.
Nonetheless, we believe that relatively low natural gas prices will persist over the long-term. Together with the lower
operating costs of natural gas-fired power plants, the higher energy generating efficiencies of modern gas turbines, and the
requirements for grid resiliency should sustain the demand for modern combined cycle and simple cycle gas-fired power
plants in the future. Natural gas is relatively clean burning, cost-effective and reliable. We believe that its benefits as a
source of power are compelling, especially as a complement to the growing deployment of wind and solar powered energy
sources. We continue to believe that the future long-term prospects for natural gas-fired power plant construction remain
generally favorable as natural gas continues to be the primary source for power generation in our country.
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Table of Contents New gas-fired power plants incorporate major advances in gas-fired turbine technologies that have provided increased
power plant efficiencies while providing the quick starting capabilities and the reliability that are necessary to balance the
inherent intermittencies of wind and solar power plants.
It has been reported that renewables currently provide approximately 36% of electricity generation in California. Yet, the
increasing dependence on intermittent renewable energy sources, especially solar, is making it harder to ensure reliable
power in California as millions of its residents lost power during a late summer heat wave in 2020. With hopes of
preventing future rolling blackouts in California, regulators there approved the acquisition of five emergency natural gas-
fueled electricity generators with an aggregate power output of approximately 150 MW. Analysis of the causes of last
winter’s widespread power outages in Texas during a frigid stretch of weather is complex. The residents of Texas suffered
as the severe cold froze wind turbines and the lack of sun diminished the power contributions of solar powered facilities.
However, natural gas-fired power plants in Texas were forced offline as well primarily due to frozen well-site equipment
and the decisions by regulators to prioritize natural gas for residential use, which caused interruptions to the supply of
natural gas to the plants. However, in both states, the significant amount of renewable power capacity failed to rise to the
occasion. A diversity lesson from both power crises may be that fossil-fuel electricity generation sources remain critical
elements of the power generation mix in order to assure grid reliability and the avoidance of power outages.
Additionally, solar and wind energy plant developers continue to confront the problems caused by grid congestion, often
unsuccessfully. Many of these projects have been canceled because renewable plants need to be sited where the resources
are optimal, often in remote locations where the transmission systems are not robust. The costs associated with the
necessary grid upgrades may be prohibitive. U.S. offshore wind projects progress inconsistently, facing challenges in the
areas of environmental and fishery impacts, grid connection and capability and federal permitting processes. Further,
projects are confronted by shipping regulations in the U.S. that may limit the ability of developers to replicate successful
European construction and installation models. Proponents of clean energy also face political challenges. Voters in the
state of Maine were energized by local residents seeking to preserve pristine woodlands and rejected a project that would
transmit hydropower from Canada into New England.
Renewed interest in nuclear power could result in the construction of new nuclear powered, carbon-free, electricity
generation stations in the U.S. that would use smaller and more economical nuclear reactors. The deployment of small
modular reactors could mean lower construction and electricity costs through the use of simpler power plant designs,
standardized components and passive safety measures. Such plants could be built in less time than larger plants, utilize
less space and represent a viable choice for reliable power to offset the intermittencies of renewable power sources. The
increase by the U.S. in its use of nuclear power for electricity generation could have unfavorable effects on the demand
for new natural gas-fired and additional renewable energy facilities in the future.
Major advances in the safe combination of horizontal drilling techniques and hydraulic fracturing led to the boom in natural
gas supplies which have been available generally at consistently low prices. The abundant availability of cheap, less
carbon-intense and higher efficiency natural gas in the U.S. should continue to be a significant factor in the economic
assessment of future power generation capacity additions although the pace of new opportunities emerging may be
restrained and the starts of awarded EPC projects may be delayed.
We believe that it is also important to note that the plans for certain natural gas-fired power plant projects include the
integration of hydrogen-burning capabilities. While the plants will initially burn natural gas alone, it is planned by the
respective project owners that the plants will eventually burn a mixture of natural gas and green hydrogen, thereby
establishing power-generation flexibility for these plants. We believe this is a winning combination that provides
inexpensive and efficient power, enhances grid reliability and addresses the clean-air concerns of environmentalists. The
building of state-of-the-art power plants with flex-fuel capability replaces coal-fired power plants in the short term with
relatively clean gas-fired electricity generation. Further, such additions to the power generation fleet provide the potential
for the plants to burn 100% green hydrogen gas, which would provide both base load power and long duration backup
power, when the sun is not shining and the wind is not blowing, for extended periods of time and without certain harmful
air emissions.
The foregoing discussion in our “Market Outlook” does focus on the state of the domestic power market as the EPC
services business of GPS provides the predominant amount of our revenues. However, we realize that overseas power
markets may provide important new power construction opportunities for us in the future as the management of APC has
growing enthusiasm for opportunities in the electricity generation markets across Ireland and the U.K. While both of these
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Table of Contents countries are committed to the increase in energy consumption sourced from wind and the sun on the pathway to net zero
emissions, there is a recognition that these sources of electrical power are inherently variable. Other technologies will be
required to support these power sources and to provide electricity when power demands exceed the amount of electricity
supplied by these renewables. The existence of the necessary power reserve will require conventional generation sources,
typically natural gas-fired power plants. APC was awarded a significant contract late in Fiscal 2022 to build a clean burning
natural gas-fired power plant in Northern Ireland so that existing coal-fired power sources there can be shut-down.
The U.K. usually holds auctions for power capacity about four years in advance of the delivery date and another auction
for a smaller amount of capacity around a year before delivery. Evidence of the shifting power generation priorities in the
U.K. are reflected in the results for Britain's auction to ensure enough electricity capacity for 2022/23 that were released
in February 2022. Capacity cleared at a record high price. A total of nearly 5 gigawatts of capacity was procured in this
auction, with nearly 70% of the power associated with gas-fired plants, a provisional auction document showed.
The Irish government recently issued a policy statement on the security of the electricity supply in Ireland which confirms
the requirement for the development of new support technologies to deliver on its commitment to have 80% of the
country’s electricity generated from renewables by 2030. The report emphasizes that this will require a combination of
conventional generation (typically powered by natural gas), interconnection to other jurisdictions, demand flexibility and
other technologies such as energy storage (i.e., batteries) and generation from renewable gases (i.e., biomethane and/or
hydrogen produced from renewable sources). The Irish government has approved that the development of new
conventional generation (including gas-fired and gasoil distillate-fired generation) is a national priority and should be
permitted and supported in order to ensure the security of electricity supply while supporting the growth of renewable
electricity generation. Since January 31, 2022, the Irish operations of APC have received limited notices to proceed with
early activities related to the construction of two new gas-fired power plant facilities near Dublin.
Further, the Irish government has recognized that the successful development of data centers in the country is a key aspect
in promoting Ireland as a digital economy hot-spot in Europe. In the absence of data centers, Ireland would be experiencing
much more modest electricity demand growth, consistent with population growth and the general development of industrial
demand. However, the stewards of the electricity supply in Ireland recognize that the large increase in electricity demand
presented by the growth of the data center industry represents an evolving, significant risk to the security of the supply.
Accordingly, guidelines have been published recently with the intent to protect both electricity consumers and the security
of supply while continuing to allow data centers to connect to the electricity system. Assessment criteria for applications
of data centers to obtain grid connections include, among other items, the ability of data center applicants to bring onsite
dispatchable power generation (and/or storage) equivalent to or greater than their demand in order to support the security
of supply. It is expected that any dispatchable on-site generation that uses fossil fuel sources developed by data center
operators will use natural gas as the fuel source; again, natural gas is considered to be a transitional fuel in Ireland’s efforts
to meet its climate action plan targets. As identified above, earlier this year, APC was awarded a project to install natural
gas-fired power generation for a major data center in the Dublin area.
In a previous section of this 2022 Annual Report, we identified that there are risks to our businesses, particularly APC,
related to the war in Ukraine. However, our APC business may benefit from an increased focus by European Union
countries on the import of liquid natural gas as an alternative to piped supplies from Russia. The construction of new
conversion facilities, pipelines and power plants could provide new construction opportunities for us.
APC is actively pursuing new business opportunities in both the renewable and support sectors with its existing and new
clients. The governments of Ireland and the U.K. have already made funds available to develop and support specific
projects. The engineering and construction teams of APC are engaged in continuous discussions with particular
stakeholders in certain of these projects and they are confident that APC will be part of their eventual execution.
Over the past few years, GPS has provided top management guidance and project management expertise to APC as it
completed its subcontract efforts for the TeesREP power plant and won the award of the project to build the new gas-fired
power plant in Northern Ireland. APC has provided project management manpower to GPS on several of its EPC services
contracts. These recent experiences have demonstrated that the two companies can combine resources effectively.
Considerations of the manner in which GPS and APC can work together in the future are becoming more formal in view
of emerging new business opportunities in the U.K. and Ireland, the strength of the reputation of GPS for successfully
completing large gas-fired power plant projects in the U.S. and the growing recognition in the power community in the
British and Irish islands that APC is committed to and capable of tackling larger and more complex power projects.
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Table of Contents We are committed to the rational pursuit of new construction projects, including those with overseas locations and unique
deployments of power-generation turbines, and the future growth of our revenues. This may result in additional decisions
to make investments in the development and/or ownership of new projects. Because we believe in the strength of our
balance sheet, we are willing to consider certain opportunities that include reasonable and manageable risks in order to
assure the award of the related engineering, procurement, construction or equipment installation services contracts to us.
The competitive landscape for our core EPC services business related to natural gas-fired power plants in the U.S. has
changed significantly over the last five years. While the domestic market remains dynamic, we are moving into an era
where there may be fewer competitors for new gas-fired power plant EPC services project opportunities. Several major
competitors have exited the market for a variety of reasons or have been acquired. Others have announced intentions to
avoid entering into fixed-price contracts. Nonetheless, the competition for new utility-scale gas-fired power plant
construction opportunities is fierce and still includes multiple global firms.
We believe that the Company has a reputation as an accomplished, dependable and cost-effective provider of EPC and
other large project construction contracting services. With the proven ability to deliver completed power facilities,
particularly combined cycle, natural gas-fired power plants, we are focused on expanding our position in the power markets
of the U.S., Ireland and the U.K. where we expect investments to be made based on forecasts of electricity demand covering
decades into the future. We believe that our expectations are valid and that our plans for the future continue to be based
on reasonable assumptions.
Comparison of the Results of Operations for the Years Ended January 31, 2022 and 2021
We reported net income attributable to our stockholders of $38.2 million, or $2.40 per share, for Fiscal 2022. For the
prior year, we reported net income attributable to our stockholders of $23.9 million, or $1.51 per diluted share. The
following schedule compares our operating results for Fiscal 2022 and Fiscal 2021 (dollars in thousands).
2022
Years Ended January 31,
$ Change
2021
% Change
REVENUES
Power industry services
Industrial fabrication and field services
Telecommunications infrastructure services
Revenues
COST OF REVENUES
Power industry services
Industrial fabrication and field services
Telecommunications infrastructure services
Cost of revenues
GROSS PROFIT
Selling, general and administrative expenses
Impairment losses
INCOME FROM OPERATIONS
Other income, net
INCOME BEFORE INCOME TAXES
Income tax expense
NET INCOME
Net loss attributable to non-controlling interests
NET INCOME ATTRIBUTABLE TO
$ 398,089 $ 319,353 $
97,890
13,391
509,370
65,263
7,590
392,206
317,130
81,391
11,117
409,638
99,732
47,321
7,901
44,510
2,552
47,062
(11,356)
35,706
(2,538)
266,993
57,257
5,889
330,139
62,067
39,041
—
23,026
1,859
24,885
(1,074)
23,811
(40)
78,736
32,627
5,801
117,164
50,137
24,134
5,228
79,499
37,665
8,280
7,901
21,484
693
22,177
(10,282)
11,895
(2,498)
24.7 %
50.0
76.4
29.9
18.8
42.2
88.8
24.1
60.7
21.2
100.0
93.3
37.3
89.1
(957.4)
50.0
NM
THE STOCKHOLDERS OF ARGAN, INC.
$
38,244 $
23,851 $
14,393
60.3
NM – Not meaningful.
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Table of Contents
Revenues
Power Industry Services
The revenues of the power industry services business increased by 24.7%, or $78.7 million, to $398.1 million for Fiscal
2022 compared with revenues of $319.4 million for Fiscal 2021. The revenues of this business represented 78.2% of
consolidated revenues for Fiscal 2022 and 81.4% of consolidated revenues for the prior year.
The primary drivers for the strong performance by this reportable segment for Fiscal 2022 were increased revenues
associated with the construction of the Guernsey Power Station and the new Maple Hill Solar energy facility, which
together represented 66.7% of consolidated revenues. Last year, the revenues of this segment included primarily revenues
associated with the construction of the Guernsey Power Station project and the TeesREP project, which together
represented 76.1% of consolidated revenues for Fiscal 2021.
Industrial Fabrication and Field Services
The revenues of industrial fabrication and field services (representing the business of TRC) increased by $32.6 million, or
50.0%, to $97.9 million for Fiscal 2022, providing 19.2% of consolidated revenues for Fiscal 2022. Revenues of TRC for
Fiscal 2021 represented approximately 16.6% of corresponding consolidated revenues. The improved current year
business of TRC reflects increased project activity for several customers, primarily in field services, as they loosened
COVID-19 work restrictions.
Telecommunications Infrastructure Services
The revenues of this business segment (representing the business of SMC) were $13.4 million for Fiscal 2022 compared
with revenues of $7.6 million for Fiscal 2021, which reflected strong performance by both the inside-premises and outside-
premises groups as certain customers in this segment also loosened COVID-19 work restrictions.
Cost of Revenues
Due primarily to the increase in consolidated revenues for Fiscal 2022 compared with revenues for Fiscal 2021,
consolidated cost of revenues also increased. These costs were $409.6 million and $330.1 million for Fiscal 2022 and
Fiscal 2021, respectively.
For Fiscal 2022, we reported a consolidated gross profit of approximately $99.7 million, which represented a gross
profit percentage of approximately 19.6% of corresponding consolidated revenues. The gross profit for the period reflected
primarily the profit contributions of efficient construction activities related to the major projects of the power industry
services reporting segment, the improved business of the industrial services segment and the revenues associated with the
settlement of a legal matter. The gross profit percentages of corresponding revenues for the power industry services,
industrial services and the telecommunications infrastructure segments for Fiscal 2022 were 20.3%, 16.9% and 17.0%,
respectively.
For Fiscal 2021, we reported a consolidated gross profit of approximately $62.1 million which represented a gross profit
percentage of approximately 15.8% of corresponding consolidated revenues. The gross profit percentages of
corresponding revenues for the power industry services, industrial services and the telecommunications infrastructure
segments for Fiscal 2021 were 16.4%, 12.3% and 22.4%, respectively. We believe that the gross margin percentages for
Fiscal 2021 are indicative of the percentages that should be expected for Fiscal 2023.
Selling, General and Administrative Expenses
These costs were $47.3 million and $39.0 million for Fiscal 2022 and Fiscal 2021, respectively, representing 9.3% and
10.0% of consolidated revenues for the corresponding periods, respectively. The 21.2% increase in these expenses between
years occurred within each of our reporting segments primarily due to increased personnel and associated costs, including
cash incentive and stock compensation expenses, and business development costs. The costs for Fiscal 2022 also included
the provision for credit losses in the amount of $2.4 million. The amount of the provision for credit losses for Fiscal 2021
was insignificant.
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Table of Contents Impairment Loss
During the fourth quarter of Fiscal 2022, we recorded an impairment loss related to the capitalized project development
costs of the Chickahominy Power Station project in the amount of $7.9 million as discussed above, of which $2.5 million
was attributed to the non-controlling interest. We did not record any goodwill or other intangible asset impairment losses
during Fiscal 2022.
Other Income
For Fiscal 2022 and Fiscal 2021, the net amounts of other income were $2.6 million and $1.9 million, respectively, which
represented an increase of 37.3% between the comparable periods. During Fiscal 2022, APC received research and
development grant payments from the government of the U.K. related to certain qualifying works performed during Fiscal
2019 in the total amount of approximately $1.7 million. In addition, APC received COVID-19 relief from the Irish
government, which amounted to approximately $1.1 million. This line item also included our share of the net loss reported
by the solar fund investment for Fiscal 2022 in the amount of $0.5 million that is discussed in Note 13 to the accompanying
consolidated financial statements.
Typically, the amounts reported on this line include primarily income earned on funds maintained in money market
accounts and interest income earned on bank certificates of deposit. Adverse economic reactions to the uncertainties of the
COVID-19 pandemic commenced during the middle of Fiscal 2021, including sharp reductions in investment interest
rates. Other income from earnings on our temporary investments of excess cash for Fiscal 2022 was insignificant although
the aggregate amount of invested funds increased between the periods. For Fiscal 2021, the net amount of other income of
$1.9 million included primarily earnings on our temporary investments of excess cash before the pandemic.
Income Taxes
We recorded income tax expense for Fiscal 2022 in the net amount of approximately $11.4 million due to our reporting
pre-tax income for financial reporting purposes in the amount of $47.1 million for the year. Our annual effective income
tax rate for Fiscal 2022 was 24.1%. This tax rate differs from the statutory federal tax rate of 21% due primarily to the
effects of state income taxes and nondeductible executive compensation.
For Fiscal 2021, we recorded income tax expense of $1.1 million, which amount was reduced significantly by the NOL
carryback benefit in the approximate amount of $4.4 million that is also described in Note 13 to the accompanying
consolidated financial statements.
Liquidity and Capital Resources as of January 31, 2022
Our working capital increased by $14.2 million to $284.3 million as of January 31, 2022 from $270.1 million as of January
31, 2021, due primarily to the net income earned during Fiscal 2022 attributable to the stockholders of Argan, offset
partially by the effects of cash payments for dividends and share repurchases. However, our balance of cash and cash
equivalents declined by a net amount of $16.2 million during Fiscal 2022 as the net change in our operating assets and
liabilities represented a use of cash of approximately $28.9 million for the year.
The net amount of cash provided by operating activities for Fiscal 2022 was $28.4 million. Our net income for Fiscal 2022,
adjusted favorably by the net amount of non-cash income and expense items, represented a source of cash in the total
amount of $57.3 million. The sources of cash from operations for Fiscal 2022 also included a decrease in the balance of
contract assets of $21.7 million, primarily due to the settlement of a legal matter by GPS (see Note 11 of the accompanying
consolidated financial statements). Reduction in the balances of contract liabilities and accounts payables and accrued
expenses, in the amounts of $44.2 million and $5.7 million, respectively, represented uses of cash during Fiscal 2022.
Non-operating activities used cash during Fiscal 2022, including $20.4 million used to repurchase shares of our common
stock pursuant to our share repurchase program (see Item 5 in Part II of this Annual Report). Additionally, we used cash
in the amount of $15.7 million for the payment of regular cash dividends. Our investment in solar energy projects used
cash in the amount of $5.0 million and capital expenditures totaled $1.4 million during Fiscal 2022. Partially offsetting
these uses of cash, we received cash proceeds related to the exercise of stock options during Fiscal 2022 in the amount of
$1.4 million. As of January 31, 2022, there were no restrictions with respect to inter-company payments between GPS,
TRC, APC, SMC and the holding company.
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Table of Contents During Fiscal 2021, our balance of cash and cash equivalents increased by $199.3 million to $366.7 million while our
working capital decreased by $7.6 million to $270.1 million as of January 31, 2021 from $277.7 million as of January 31,
2020 due primarily to the amount of regular and special cash dividends paid during the year.
The net amount of cash provided by operating activities for Fiscal 2021 was $176.0 million. Our net income for Fiscal
2021, adjusted favorably by the net amount of non-cash income and expense items, represented a source of cash in the
total amount of $41.5 million. The sources of cash from operations for Fiscal 2021 also included a temporary increase in
the balance of contract liabilities associated with the early phases of construction activities on projects of GPS and TRC
in the amount of $99.4 million. A reduction in the balances of accounts receivable and contract assets, primarily at the
TRC and APC operations, provided cash in the amounts of $8.5 million and $6.7 million, respectively. In addition, the
combined level of accounts payable and accrued expenses increased by $31.4 million during Fiscal 2021, a source of cash
for the year.
Fiscal 2021 also reflected an entry to record the carryback of our NOL incurred for Fiscal 2020 to prior income tax years.
The loss carryback should result in a refund of federal income taxes in the amount of $12.7 million. This tax refund
receivable was included in the balance of other current assets as of January 31, 2021, which was the primary cause of the
net increase in this balance of $11.5 million during Fiscal 2021, which represented a use of cash.
Primary sources of cash for Fiscal 2021 were the net maturities of short-term investments, certificates of deposit issued by
the Bank, in the amount of $70.0 million. Non-operating activities used cash during Fiscal 2021, including the payment of
regular and special cash dividends in the total amount of $47.0 million. During Fiscal 2021, capital expenditures were
reduced by approximately 76.1% to $1.7 million from a capital expenditures amount of $7.1 million for Fiscal 2020. We
also used cash in the amount of $1.3 million during Fiscal 2021 to make an investment in a solar energy project. Partially
offsetting these uses of cash, we received cash proceeds related to the exercise of stock options during Fiscal 2021 in the
amount of $1.6 million.
At January 31, 2022, most of our balance of cash and cash equivalents was invested in government and prime money
market funds with most of their total assets invested in cash, U.S. Treasury obligations and repurchase agreements secured
by U.S. Treasury obligations. The major portion of our domestic operating bank account balances are maintained with the
Bank. We do maintain certain Euro-based bank accounts in the Ireland and certain pound sterling-based bank accounts in
the U.K. in support of the operations of APC.
The original term of our Credit Agreement with the Bank was scheduled to expire on May 31, 2021. During April 2021,
the Company and the Bank agreed to an amendment to the Credit Agreement which extended the expiration date of the
Credit Agreement to May 31, 2024 and reduced the borrowing rate. The Credit Agreement, as amended, includes the
following features, among others: a lending commitment of $50.0 million including a revolving loan with interest at the
30-day LIBOR plus 1.6% (reduced from 2.0%), and an accordion feature which allows for an additional commitment
amount of $10.0 million, subject to certain conditions. We may also use the borrowing ability to cover other credit
instruments issued by the Bank for our use in the ordinary course of business as defined by the Bank. At January 31, 2022,
we had no outstanding borrowings, however the Bank has issued letters of credit in the total outstanding amount of $21.5
million in support of the activities of APC under new customer contracts. In connection with the project development
activities of the VIE, the Bank issued a letter of credit, outside the scope of the Credit Agreement, in the approximate
amount of $3.4 million for which we have provided cash collateral. The Company expects to amend the Credit Agreement
during Fiscal 2023 in order to replace LIBOR with an equivalent benchmark rate. The Company does not expect that the
change will materially impact its consolidated financial statements.
We have pledged the majority of our assets to secure the financing arrangements. The Bank’s consent is not required for
acquisitions, divestitures, cash dividends or significant investments as long as certain conditions are met. The Credit
Agreement, as amended, requires that we comply with certain financial covenants at our fiscal year-end and at each fiscal
quarter-end, and includes other terms, covenants and events of default that are customary for a credit facility of its size
and nature, including a requirement to achieve positive adjusted earnings before interest, taxes, depreciation and
amortization, as defined, over each rolling twelve-month measurement period. At January 31, 2022 and 2021, we were
compliant with the covenants of the Credit Agreement, as amended.
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Table of Contents In the normal course of business and for certain major projects, we may be required to obtain surety or performance
bonding, to provide parent company guarantees, or to cause the issuance of letters of credit (or some combination thereof)
in order to provide performance assurances to clients on behalf of one of our subsidiaries.
If our services under a guaranteed project would not be completed or would be determined to have resulted in a material
defect or other material deficiency, then we could be responsible for monetary damages or other legal remedies. As is
typically required by any surety bond, we would be obligated to reimburse the issuer of any surety bond issued on behalf
of a subsidiary for any cash payments made thereunder. The commitments under performance bonds generally end
concurrently with the expiration of the related contractual obligation. Not all of our projects require bonding.
As of January 31, 2022, the value of the Company’s unsatisfied bonded performance obligations, covering all of its
subsidiaries, was approximately $235.1 million. In addition, as of January 31, 2022, there were bonds outstanding in the
aggregate amount of approximately $1.0 million covering other risks including warranty obligations related to completed
activities; the majority of these bonds expire at various dates during Fiscal 2023.
We have also provided a financial guarantee on behalf of GPS to an original equipment manufacturer in the amount of
$3.6 million to support project developmental efforts. During Fiscal 2022, the Company established a liability for an
estimated loss related to this guarantee.
When sufficient information about claims related to our performance on projects would be available and monetary
damages or other costs or losses would be determined to be probable, we would record such losses. As our subsidiaries
are wholly-owned, any actual liability related to contract performance is ordinarily reflected in the financial statement
account balances determined pursuant to the Company’s accounting for contracts with customers. Any amounts that we
may be required to pay in excess of the estimated costs to complete contracts in progress as of January 31, 2022 are not
estimable.
Returns on money market instruments and certificates of deposit are currently minimal due to market conditions. With the
desire to increase the amount of return on its available cash, the Company invested approximately $5.0 million during
Fiscal 2022, in a limited liability company that makes equity investments in solar energy projects that are eligible to receive
energy tax credits (see Note 13 to the accompanying consolidated financial statements). During Fiscal 2021, we made a
similar investment in the amount of $1.3 million. The Fiscal 2022 investment is expected to provide an overall return of
approximately 20% over the six-year expected life of our investment. It is likely that we will evaluate opportunities to
make other solar energy investments of this type in the future.
We believe that cash on hand, our cash equivalents, cash that will be provided from the maturities of short-term investments
and cash generated from our future operations, with or without funds available under our Credit Agreement, will be
adequate to meet our general business needs in the foreseeable future. In general, we maintain significant liquid capital in
our consolidated balance sheet to ensure the maintenance of our bonding capacity and to provide parent company
performance guarantees for EPC and other construction projects.
However, any significant future acquisition, investment or other unplanned cost or cash requirement, may require us to
raise additional funds through the issuance of debt and/or equity securities. There can be no assurance that such financing
will be available on terms acceptable to us, or at all.
Contractual Obligations
During 2022, there was no significant change in the nature or amounts of our contractual obligations. The amount of
contract obligations disclosed as of January 31, 2021 was $8.2 million. The two largest items included in this total,
operating leases and deferred compensation, are amounts included as liabilities in our consolidated balance sheet. The
remainder of the disclosed amount related primarily to open service arrangements. Outstanding commitments represented
by open purchase orders and subcontracts related to our construction contracts have not been included in the disclosed
amounts as such amounts are expected to be funded through contract billings to customers. We do not have any significant
obligations for materials or subcontracted services beyond those required to completed construction contracts awarded to
us.
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Table of Contents Special Purpose Entities
As is common in our industry, EPC contractors and third parties form joint ventures, limited partnerships and limited
liability companies for purposes of executing a project or program for a project owner. These teaming arrangements are
typically dissolved upon completion of the project or program.
In addition, we may obtain interests in VIEs formed by its owners for a specific purpose. The evaluation of whether such
interests represent our financial control of a VIE requires analysis and judgement. We concluded that we are the primary
beneficiary of a VIE formed by an independent firm for the purpose of developing a natural gas-fired power plant in
Virginia. As a result, the VIE is included in our consolidated financial statements until we determine that our financial
control of the entity has passed to another party. Pursuant to agreements negotiated with the developer, we lent funds to
the VIE to cover certain costs of the project development effort. The development phase activities of the VIE were focused
on 1) obtaining the necessary permits to build and operate the power plant, 2) completing arrangements to connect the
power plant to the fuel supply and the electricity grid, 3) engaging energy plant operators in negotiations for the purchase
of project ownership interests, and 4) securing permanent financing for the project. For consolidated reporting purposes,
these costs have been presented as project development costs and included in property, plant and equipment. During Fiscal
2022, as described in Note 3 to the accompanying consolidated financial statements, we recorded an impairment loss
related to these costs in the amount of $7.9 million, of which $2.5 million was attributed to the non-controlling interest.
We have entered into similar support arrangements with other independent parties in the past that resulted in the successful
development of three separate gas-fired power plant projects where we were paid project development fees in the total
amount of $29.6 million, and where our loans in the amount of $11.7 million were repaid in full plus interest in the amount
of $2.3 million. In each of these cases, we deconsolidated the corresponding VIE when we were no longer the primary
beneficiary.
We may enter into other support arrangements in the future in connection with power plant development opportunities
when they arise and when we are confident that providing early financial support for the projects will lead to the award of
the corresponding EPC contracts to us.
Earnings before Interest, Taxes, Depreciation and Amortization
We believe that EBITDA is a meaningful presentation that enables us to assess and compare our operating cash flow
performance on a consistent basis by removing from our operating results the impacts of our capital structure, the effects
of the accounting methods used to compute depreciation and amortization and the effects of operating in different income
tax jurisdictions. Further, we believe that EBITDA is widely used by investors and analysts as a measure of performance.
However, as EBITDA is not a measure of performance calculated in accordance with U.S. GAAP, we do not believe that
this measure should be considered in isolation from, or as a substitute for, the results of our operations presented in
accordance with US GAAP that are included in our consolidated financial statements. In addition, our EBITDA does not
necessarily represent funds available for discretionary use and is not necessarily a measure of our ability to fund our cash
needs.
The following table presents the determinations of EBITDA for Fiscal 2022 and Fiscal 2021, respectively (amounts in
thousands).
Net income, as reported
Income tax expense
Depreciation
Amortization of purchased intangible assets
EBITDA
EBITDA of non-controlling interests
EBITDA attributable to the stockholders of Argan, Inc.
2022
2021
$ 35,706 $ 23,811
1,074
3,715
904
29,504
(40)
$ 53,837 $ 29,544
11,356
3,367
870
51,299
(2,538)
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Table of Contents
As we believe that our net cash flow provided by or used in operations is the most directly comparable performance
measure determined in accordance with accounting principles generally accepted in the U.S. (“U.S. GAAP”), the following
table reconciles the amounts of EBITDA for the applicable years, as presented above, to the corresponding amounts of net
cash flows provided by operating activities that are presented in our consolidated statements of cash flows for Fiscal 2022
and Fiscal 2021 (amounts in thousands).
EBITDA
Current income tax (expense) benefit
Stock compensation expense
Impairment loss
Other non-cash items
(Increase) decrease in accounts receivable
Increase in other assets
(Decrease) increase in accounts payable and accrued expenses
Change in contracts in progress, net
Net cash provided by operating activities
2022
2021
$ 51,299 $ 29,504
6,571
2,938
—
2,461
8,463
(11,467)
31,442
106,101
$ 28,415 $ 176,013
(11,564)
3,459
7,901
6,196
(480)
(241)
(5,742)
(22,413)
Critical Accounting Policies and Estimates
We consider the accounting policies discussed below related to revenue recognition on long-term construction contracts;
income tax reporting; the valuation of goodwill; and the financial reporting associated with any significant claims or legal
matters to be most critical to the understanding of our financial position and results of operations, as well as the accounting
and reporting for special purpose entities including variable interest entities.
Critical accounting policies are those related to the areas where we have made what we consider to be particularly
subjective or complex judgments in arriving at estimates and where these estimates can significantly impact our financial
results under different assumptions and conditions.
These estimates, judgments, and assumptions affect the reported amounts of assets, liabilities and equity, the disclosure of
contingent assets and liabilities at the date of financial statements and the reported amounts of revenues and expenses
during the reporting periods. We base our estimates on historical experience and various other assumptions that we believe
are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value
of assets, liabilities and equity that are not readily apparent from other sources. Actual results and outcomes could differ
from these estimates and assumptions. We do periodically review these critical accounting policies and estimates with the
audit committee of our board of directors.
Revenue Recognition
Our revenues are primarily derived from construction contracts that can span several quarters or years. We enter into EPC
and other long-term construction contracts principally on the basis of competitive bids or in conjunction with our support
of the development of power plant projects. The types of contracts may vary. However, the EPC contracts of our power
industry services reporting segment, and most other large contracts awarded to our other companies, are fixed-price
contracts. Revenues are recognized primarily over time as performance obligations are satisfied due to the continuous
transfer of control to the project owner or other customer. The accuracy of our revenues and profit recognition in a given
period depends on the accuracy of our estimates of the forecasted contract value, or transaction price, and the cost to
complete the work for each project.
Central to accounting for revenues from contracts with customers is a five-step revenue recognition model that requires
reporting entities to:
Identify the contract,
Identify the performance obligations of the contract,
1.
2.
3. Determine the transaction price of the contract,
4. Allocate the transaction price to the performance obligations, and
5. Recognize revenue.
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The guidance focuses on the transfer of the control of the goods and/or services to the customer, as opposed to the transfer
of risk and rewards. Major provisions cover the determination of which goods and services are distinct and represent
separate performance obligations, the appropriate treatment of variable consideration, and the evaluation of whether
revenues should be recognized at a point in time or over time. In general, application of the rules requires us to make
important judgements and meaningful estimates that may have significant impact on the amounts of revenues recognized
by us for any reporting period.
Revenues from fixed price contracts, including a portion of estimated profit, are recognized over time, based on costs
incurred and estimated total contract costs using the percentage-of-completion method. The cost and profit estimates are
determined at least quarterly for all significant contracts pursuant to a detailed “bottoms-up” review process. The results
of the process are subjected to reviews by senior management at each subsidiary. The percentage-of-completion method
measures the ratio of costs incurred and accrued to date for each contract to the estimated total cost for each contract at
completion. This requires us to prepare on-going estimates of the cost to complete each contract as the project progresses.
In preparing these estimates, we make significant judgments and assumptions about our significant costs, including
materials, labor and equipment, and we evaluate contingencies based on possible schedule variances, production delays or
other productivity factors.
Actual costs may vary from the costs we estimate. Variations from estimated contract costs, along with other risks inherent
in fixed-price contracts, may result in actual revenues and gross profits differing from those we estimate and could result
in losses on projects or other significant unfavorable impacts on our operating results for any fiscal quarter or year. If a
current estimate of total contract cost indicates a loss on a contract, the projected loss is recognized in full when determined,
without regard to the percentage of completion. There are a number of factors that can contribute to changes in estimated
contract costs, revenues and profitability. The most significant of these are identified in the first item included in the Risks
Related to our Operational Execution section of Part I, Item 1A. of this Annual Report entitled Risk Factors.
Crucial to the compliance with the accounting standard covering the recognition of revenues on contracts with customers
is the identification of the promises made to the customer by us that are included in the contract. If a promise is distinct,
as that concept is defined in the accounting standard, it represents a separate performance obligation. Contracts may have
multiple performance obligations. The amounts of revenue associated with each promise are recognized when, or as, the
performance obligations are satisfied. However, complex contracts may include only one performance obligation if the
multiple promises are not distinct within the context of the contract. For example, if the promises that could be considered
distinct are interrelated or require us to perform integration so that the customer receives a complete product, the contract
is considered to include only one performance obligation. Most of our long-term contracts have a single performance
obligation as the promises to transfer individual goods or services are not separately identifiable from other promises
within the context of the contract. Our EPC contracts require us to deliver a complete and functioning power plant, not
just functioning components.
The transaction price of a contract represents the value used to determine the amount of revenues recognized as of the
balance sheet date. It may reflect amounts of variable consideration, which could be either increases or decreases to the
transaction price. These adjustments can be made from time-to-time during the period of contract performance as
circumstances evolve related to such items as variations in the scope and price of contracts, claims, incentives and
liquidated damages.
The Company may include an estimated amount of variable consideration in the transaction price to the extent it is probable
that a significant reversal of cumulative revenues recognized on the particular contract will not occur when the uncertainty
associated with the variable consideration is resolved. The Company’s determination of the amount of variable
consideration to be included in the transaction price of a particular contract is based largely on an assessment of the
Company’s anticipated performance and all information (historical, current and forecasted) that is reasonably available.
The effect of any revisions to the transaction price on the amount of previously recognized revenues that is due to the
addition or reduction of variable consideration is recorded currently as an adjustment to revenues on a cumulative catch-
up basis. In the event that any amounts of variable consideration that are reflected in the transaction price of a contract are
not resolved in the Company’s favor, there could be reductions in, or reversals of, previously recognized revenues. In most
significant instances, modifications to our contracts do not represent the addition of new performance obligations.
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Contract results may be impacted by estimates of the amounts of contract variations that we expect to receive. The effects
of any resulting revisions to revenues and estimated costs can be determined at any time and they could be material. As of
January 31, 2021, the aggregate amount of contract variations reflected in estimated contract transaction prices was $16.6
million, including $6.8 million related to our EPC services contract with Exelon. During Fiscal 2022, this amount was
recovered in full in connection with the settlement of the litigation with Exelon. As of January 31, 2022, the aggregate
amount of contract variations reflected in estimated transaction prices was $7.5 million.
Our long-term contracts typically have schedule dates and other performance obligations that, if not achieved, could
subject us to liquidated damages. These contract requirements generally relate to specified activities that must be
completed by an established date or by achievement of a specified level of output or efficiency. Each contract defines the
conditions under which a project owner may make a claim for liquidated damages. The amounts of liquidated damages
owed to a project owner pursuant to the terms of a contract would represent reductions of the transaction price of the
corresponding contract.
At the outset of each of the Company’s contracts, the potential amounts of liquidated damages typically are not subtracted,
from the transaction price as the Company believes that it has included activities in its contract plan, and has reflected the
associated costs in its forecasts of completed contract costs, that will be effective in preventing such damages. Of course,
circumstances may change as the Company executes the corresponding contract. The transaction price is reduced by an
applicable amount when the Company no longer considers it probable that a future reversal of revenues will not occur
when the matter is resolved. In general, we consider potential liquidated damages, the costs of other related items and
potential mitigating factors in determining the estimates of forecasted revenues and the adequacy of our estimates of the
cost to complete contracts.
Goodwill
In connection with the acquisitions of GPS, TRC and APC, we recorded substantial amounts of goodwill and other
purchased intangible assets including contractual and other customer relationships, non-compete agreements, trade names
and certain fabrication process certifications. We utilized the assistance of a professional appraisal firm in the initial
determinations of goodwill and the other purchased intangible assets for these acquisitions which were all determined to
have finite useful lives.
At January 31, 2022, the goodwill balances related to the acquisitions of GPS, TRC and SMC were $18.5 million, $9.5
million and $0.1 million, respectively, which together represented approximately 5.1% of consolidated total assets. The
Company performs its required annual assessments of the carrying value of goodwill balances as of November 1 each
year. We also test for impairment of goodwill more frequently if events or changes in circumstances indicate that the
carrying value of goodwill might be impaired.
In accordance with current accounting guidance, we perform testing for the impairment of goodwill by comparing the
estimated fair value of a reporting unit with the carrying amount of the unit reflected in the consolidated financial
statements, including goodwill. If the carrying amount of the reporting unit exceeds its estimated fair value, an impairment
loss is recorded for the excess, not to exceed the total amount of goodwill allocated to the reporting unit.
The balance of goodwill related to TRC and included in the consolidated balance sheet as of January 31, 2022 was $9.5
million. We performed a goodwill impairment assessment for TRC as of November 1, 2021 with the assistance of a
professional business valuation firm. It was determined that the estimated fair value of TRC exceeded the corresponding
carrying value by approximately $8.9 million; accordingly, there was no impairment loss recorded as of that date. The
estimated fair value amount for TRC determined as of November 1, 2021 reflected a weighting of results determined using
various business valuation approaches consistent with prior year valuations.
As in the past, the majority of the weighted average fair value was based on the result of modeling discounted future net-
after-tax cash flows of the business. The discounted cash flows of TRC were based on a management forecast of operating
results. Last year, the result of a similarly completed assessment of TRC indicated that the excess of its estimated fair
value over carrying value was $1.5 million.
Judgments inherent in these approaches include the determination of appropriate discount rates, the amount and timing of
expected future cash flows, growth rates for revenues and gross margins, and appropriate benchmark companies. The
estimated future cash flows used for TRC were based on five-year financial forecasts developed internally by management.
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Table of Contents Our discount rate assumptions were based on an assessment of the equity cost of capital and the appropriate capital
structure for our reporting unit. Material assumptions used in the impairment assessment included the weighted average
cost of capital percent and terminal growth rates.
The widening of the excess of estimated fair value over carrying value for TRC during Fiscal 2022 was due primarily to
an improved forecast of future results. In view of the strong results reported by TRC during Fiscal 2022, we believe that
the current forecast of the operating results of TRC is based on reasonable assumptions and, in particular, the following
factors. The average amount of annual revenues during the five-year period ending January 31, 2027 is forecasted to be
$102.2 million, with a terminal revenues annual growth rate of 3% thereafter. The actual amount of revenues recognized
by TRC for Fiscal 2022 was $97.9 million. Annual earnings before interest and taxes are forecast to increase from 4.8%
of revenues for the year ending January 31, 2023 to 6.2% of revenues by the year ending January 31, 2027, with a terminal
percentage of 6.8% of corresponding revenues. The actual amount of such earnings for Fiscal 2022 was 11.6% of
corresponding revenues. Should unfavorable operating results in the future indicate that the forecast for TRC is too
optimistic, we may reduce it. This could result in a shrinking of the excess or even a future impairment loss.
In certain situations, we use an alternative approach which allows us to first assess qualitative factors to decide whether it
is necessary to perform the quantitative goodwill impairment test. We are not required to calculate the fair value of a
reporting unit unless we determine, based on a qualitative assessment, that it is more likely than not that its fair value is
less than the corresponding carrying value. The professional guidance includes discussions of the types of factors which
should be considered in conducting the qualitative assessment including macroeconomic, industry, market and entity-
specific factors. Using this approach, we concluded that it was more likely than not that the fair value of the GPS reporting
unit exceeded the corresponding carrying value as of November 1, 2021. Therefore, completion of the quantitative
impairment assessment was considered to be unnecessary. No events associated with the business of GPS occurred in the
period from the assessment date through January 31, 2022 that would cause us to reconsider that conclusion.
Uncertain Income Tax Positions
As we have disclosed in the “Research and Development Tax Credits” section of Note 13 to the accompanying
consolidated financial statements, during Fiscal 2019 we completed a detailed review of the activities of our engineering
staff on major EPC services projects in order to identify and quantify the amounts of research and development credits
available to reduce prior year income taxes. This extensive study focused on the costs incurred on specific projects during
the three-year period ended January 31, 2018. Based on the results of the study, we identified and estimated significant
amounts of income tax benefits that were not previously recognized in our financial results for any prior year reporting
period.
Under current professional accounting guidance, income tax positions must meet a more-likely-than-not recognition
threshold to be recognized. Income tax positions that previously failed to meet the more-likely-than-not threshold are
recognized in the first subsequent financial reporting period in which that threshold is met. Fiscal 2019 was the initial
reporting period in which we had sufficient data on which to make an evaluation and to reach a conclusion on the amount
of income tax credit benefits related to prior year project costs that, more likely than not, qualified as research and
development costs under the Internal Revenue Code and the rules and regulations of certain states. The net amount of the
credits that we recognized in income taxes during Fiscal 2019 was $16.2 million, as subsequently reduced by $0.4 million.
Based on our judgement, the amount of income tax benefits related to identified research and development income tax
credits that we assessed as not meeting the threshold criteria for recognition was $5.1 million, for which we established a
liability related to uncertain income tax return positions that was included in accrued expenses as of January 31, 2019.
During Fiscal 2020, this amount was adjusted modestly; the liability amount as of January 31, 2022 and 2021 was $5.0
million.
The research and development credits were included in amendments to our consolidated federal income tax returns for
Fiscal 2016 and Fiscal 2017, that were filed in January 2019, and our consolidated federal income tax return for Fiscal
2018, that was filed in November 2018. During Fiscal 2022, the IRS issued its revenue agents reports that disagree with
our credit amounts. The differences in amounts are meaningful.
After a careful review of a preliminary reports received from the IRS, the preparation of an acknowledgement-of-facts
responses, analysis of the final reports and consultation with subject experts, we have concluded that our arguments are
sound based on our analysis of the facts, our understanding of the tax code and related regulations and our understanding
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Table of Contents of the applicable case law, and that the reports do not present any new facts relating to the issues or make any new
arguments that would cause us to make any adjustments to our accounting for the research and development claims as of
January 31, 2022. We have formally protested the findings of the IRS examiner and are pursuing our income tax positions
with the IRS through the established appeals process. We expect that our appeals hearing will occur during Fiscal 2023.
We have updated the evaluation of our income tax positions using the more-likely-than-not threshold in order to confirm
the adequacy of the liability amount carried in the balance sheet as of January 31, 2022 for uncertain income tax positions.
We have not adjusted the liability amount during Fiscal 2022 as we do not anticipate any significant changes to the net
amount of the income tax benefits recorded for research and development credits claimed for Fiscal 2016 through Fiscal
2018. However, if negotiations with the IRS or legal decisions cause us to believe that our previously recognized tax
positions no longer meet the more-likely-than-not threshold, the related net tax benefit amount will be derecognized in the
first financial reporting period in which that threshold is no longer met. Any unfavorable adjustment to our taxes could
reverse a substantial portion of the amount of net research and development credits recognized of $16.2 million, which
could materially and adversely affect our future financial condition and operating results.
Deferred Tax Assets and Liabilities
Our consolidated balance sheet as of January 31, 2022 includes net deferred tax assets in the amount of approximately
$0.5 million. The components of our deferred taxes are presented in Note 13 to the accompanying consolidated financial
statements. These amounts reflect differences in the periods in which certain transactions are recognized for financial and
income tax reporting purposes.
We consider whether it is more likely than not that some portion or all of the deferred tax assets will not be realized on a
jurisdiction-by-jurisdiction basis. Our ability to realize our deferred tax assets, including those related to the past NOLs
incurred in the U.K., that applicable income tax rules will allow us to use in order to offset future amounts of applicable
taxable income, depends primarily upon the generation of sufficient future taxable income to allow for the realization of
our deductible temporary differences. If such estimates and assumptions regarding income amounts change in the future,
we may be required to record additional valuation allowances against some or all of the deferred tax assets resulting in
additional income tax expense in our consolidated statement of earnings. During Fiscal 2020, a valuation allowance in the
amount of $7.1 million was established against the deferred tax asset amount created by the NOL of APC’s subsidiary in
the U.K. for Fiscal 2020. However, we believe that the results of operations in the U.K. have begun a turnaround that
should enable APC to utilize portions of the unrecognized NOL benefits in the future.
A deferred tax asset in the amount of $8.3 million was recorded as of January 31, 2020 associated with the income tax
benefit of our domestic NOL for Fiscal 2020 without any corresponding valuation allowance. Among other changes, the
CARES Act re-established a carryback period for certain losses to five years. The NOLs eligible for carryback under the
CARES Act include our domestic loss for Fiscal 2020, which was approximately $39.5 million. We have made the
appropriate filing with the IRS requesting carryback refunds of income taxes paid for the years ended January 31, 2017,
2016 and 2015. With the enactment of the CARES Act, the asset amount was moved to income taxes receivable
representing a complete utilization of the NOL within one year of its occurrence.
At this time, we believe that the historically strong earnings performance of our power industry services segment will
provide sufficient income during the years when most of our other deferred tax assets become deductible in the U.S. in
order for us to realize the applicable temporary income tax differences. Accordingly, we believe that it is more likely than
not that we will realize the benefit of significantly all of our net deferred tax assets.
Variable Interest Entities
This Item 7 of the 2022 Annual Report and Note 3 of the accompanying consolidated financial statements include
discussions of “Special Purpose Entities” that include variable interest entities. Determinations are made by management
regarding the accounting and disclosures for these entities including, for example, the identification of variable interests
and the consideration of control over the primary activities of the entities. During Fiscal 2022, the most important
determination related to the valuation of project development costs in our consolidated balance sheet. As explained in the
sections of this 2022 Annual Report identified above, we recorded an impairment loss in the amount of $7.9 million during
Fiscal 2022 as we came to the conclusions that the related natural gas-fired power plant project was not viable and that our
costs would not be recovered. In March 2022, the project owner made a public announcement that the power plant project,
planned to be built in Virginia, was cancelled.
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Table of Contents Legal Contingencies
We do become involved in legal matters where litigation has been initiated or claims have been made against us. At this
time, we do not believe that any material loss is probable related to any current matters. We do maintain accrued expense
balances for the estimated amounts of legal costs expected to be billed related to any significant matter. We review the
status of each matter and assess the adequacy of the accrued expense balances at the end of each fiscal quarter, and make
adjustments to the balances if necessary. Should our assessments of the outcomes of outstanding legal matters change,
significant losses or additional costs may be recorded.
During Fiscal 2022, the significant legal matter described below, for which we have been providing regular disclosure in
our filings, was settled.
In January 2019, GPS filed a lawsuit against Exelon West Medway II, LLC and Exelon Generation Company, LLC
(together referred to as “Exelon”) for Exelon’s breach of contract and failure to remedy various conditions which
negatively impacted the schedule and the costs associated with the construction by GPS of a gas-fired power plant for
Exelon in Massachusetts. Subsequently, Exelon provided GPS with a notice intending to terminate the EPC contract under
which GPS had been providing services to Exelon and served us with contractual notice requiring GPS to vacate the
construction site. At that time, the construction project was nearly complete and both of the power generation units included
in the plant had successfully reached first fire. The completion of various prescribed performance tests and the clearance
of punch-list items were the primary tasks necessary to be accomplished by GPS in order to achieve substantial completion
of the power plant. Exelon asserted that GPS failed to fulfill certain obligations under the contract and was in default,
withholding payments from GPS on invoices rendered to Exelon in accordance with the terms of the contract between the
parties.
Our firm belief that Exelon received the benefits of the construction efforts of GPS and the corresponding progress made
on the project without making payments to GPS for the value received was reflected in our accounting for the project that
we maintained throughout the duration of the dispute. There were outstanding invoices billed to Exelon and unbilled costs
incurred on the project, with substantial balances included in both accounts receivable and contract assets as of January
31, 2021. The final settlement of all outstanding claims between the parties resulting in Exelon making a payment to GPS
in the amount of $27.5 million, which amount was in excess of the total carrying amount of the related accounts receivable
and contract assets. The excess amount was included in revenues for Fiscal 2022.
Recently Issued Accounting Pronouncements
In December 2019, the Financial Accounting Standards Board issued Accounting Standards Update 2019-12, Simplifying
the Accounting for Income Taxes, which, among other changes, eliminates the exception to the general methodology for
calculating income taxes in an interim period when a year-to-date loss exceeds the expected loss for the entire year. In
these instances, the estimated annual effective income tax rate shall be used to calculate the tax without limitation. The
new standard also requires the recognition of a franchise (or similar) tax that is partially based on income as an income-
based tax and the recording of any incremental tax that is incurred by us as a non-income-based tax. The requirements of
this new guidance, effective for us on February 1, 2021, did not alter our accounting for income taxes.
There are no other recently issued accounting pronouncements that have not yet been adopted that we consider material to
our consolidated financial statements.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
In the normal course of business, our results of operations may be subject to risks related to fluctuations in interest rates.
As of January 31, 2022, we had no outstanding borrowings under our financing arrangements with the Bank as amended
(see Note 9 to the accompanying consolidated financial statements), which provide a revolving loan with a maximum
borrowing amount of $50.0 million that is available until May 31, 2024, with interest at 30-day LIBOR plus 1.6% going
forward.
During Fiscal 2022, Fiscal 2021 and Fiscal 2020, we did not enter into derivative financial instruments for trading,
speculation or other purposes that would expose us to market risk.
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Table of Contents Financial markets around the globe are preparing for the pending discontinuation of LIBOR, which is the widely used
indicator of basis for short-term lending rates. The transition from LIBOR is market driven, not a change required by
regulation. The U.S. and other countries are currently working to replace LIBOR with alternative reference rates.
We do not expect that the replacement of LIBOR as the basis for the determination of our short-term borrowing rate will
have any significant effects on our financial arrangements with the Bank or our financial reporting.
We maintain a substantial amount of our temporarily investable cash in certificates of deposit and in government and
prime money market funds (see Note 5 of the accompanying consolidated financial statements). As of January 31, 2022,
the weighted average number of days until maturity for the short-term investments and money market funds is 336 days.
The weighted average annual interest rate of our certificates of deposit of $90.0 million, which are classified as short-term
investments, and money market funds of $207.5 million was 0.07%. To illustrate the potential impact of changes in interest
rates on our results of operations, we present the following hypothetical analysis, which assumes that our consolidated
balance sheet as of January 31, 2022 remains constant, and no further actions are taken to alter our existing interest rate
sensitivity, including reinvestments. As the blended weighted average interest rate was 0.07% at January 31, 2022, the
largest decrease in the interest rates presented below is 7 basis points (dollars in thousands).
Basis Point Change
Up 300 basis points
Up 200 basis points
Up 100 basis points
Down 7 basis points
Increase (Decrease) in Increase (Decrease) in Net Increase (Decrease) in
Interest Income
Interest Expense
Income (pre-tax)
$
$
7,520
5,013
2,507
(146)
$
—
—
—
—
7,520
5,013
2,507
(146)
With the consolidation of APC, we are subject to the effects of translating the financial statements of APC from its
functional currency (Euros) into our reporting currency (U.S. dollars). Such effects are recognized in accumulated other
comprehensive income (loss), which is net of tax when applicable. APC remeasures transactions and subsidiary financial
statements denominated in local currencies to Euros. Gains and losses on the remeasurements are recorded in the other
income line of our consolidated statement of earnings.
In the “Risk Factors” section of this 2022 Annual Report (see Item 1A), we have included discussion of the risks to our
fixed price contracts if actual contract costs rise above the estimated amounts of such costs that support corresponding
contract prices. Identified as factors that could cause contract cost overruns, project delays or other unfavorable effects on
our contracts, among other circumstances and events, are delays in the scheduled deliveries of machinery and equipment
ordered by us or project owners, unforeseen increases in the costs of labor, warranties, raw materials, components or
equipment or the failure or inability to obtain resources when needed.
We are subject to fluctuations in prices for commodities including steel products, copper, concrete and fuel. Although we
attempt to secure firm quotes from our suppliers, we generally do not hedge against increases in prices for these
commodities. Commodity price risks may have an impact on our results of operations due to the fixed-price nature of
many of our contracts. We attempt to include the anticipated amounts of price increases or decreases in the costs of our
bids. In times of increased supply cost volatility, we may take other steps to reduce our risks. For example, we may hold
quotes related to materials in our industrial fabrication and field services segment for very short periods. For major fixed
price contracts in our power industry services segment, we may mitigate material cost risks by procuring the majority of
the equipment and construction supplies during the early phases of a project. The profitability of our active jobs has not
suffered meaningfully from the periodic global surges in non-residential construction material costs.
During Fiscal 2022, our operations were challenged by the well-publicized global supply chain disruptions. While the
management of the risks associated with the inability to obtain machinery, equipment and other materials when needed
continues to include our best efforts, we are concerned that the supply chain uncertainties may be impacting project
owners’ confidence in commencing new work which may adversely affect our expected levels of revenues until the supply
chain disruptions dissipate.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
See the Index to the Consolidated Financial Statements on page 57 of this 2022 Annual Report.
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Table of Contents
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE.
None.
ITEM 9A. CONTROLS AND PROCEDURES.
Attached as exhibits to this 2022 Annual Report are certifications of our Chief Executive Officer (“CEO”) and Chief
Financial Officer (“CFO”), which are required in accordance with Rule 13a-14 of the Exchange Act. This “Controls and
Procedures” section includes information concerning the controls and controls evaluation referred to in the certifications
and a reference to the report of Grant Thornton LLP, our independent registered public accounting firm, regarding its audit
of our internal control over financial reporting. This section should be read in conjunction with the certifications and the
report of Grant Thornton LLP for a more complete understanding of the topics presented.
Evaluation of Disclosure Controls and Procedures
We conducted an evaluation of the effectiveness of the design and operation of our “disclosure controls and procedures”
(“Disclosure Controls”) as of the end of the year covered by this 2022 Annual Report. The controls evaluation was
conducted under the supervision and with the participation of management, including our CEO and CFO. Disclosure
Controls are controls and procedures designed to reasonably assure that information required to be disclosed in our reports
filed under the Exchange Act, such as this 2022 Annual Report, is recorded, processed, summarized, and reported within
the time periods specified in the SEC’s rules and forms. Disclosure Controls are also designed to reasonably assure that
such information is accumulated and communicated to our management, including the CEO and CFO, as appropriate to
allow timely decisions regarding required disclosure. Our quarterly evaluation of Disclosure Controls includes an
evaluation of some components of our internal control over financial reporting, which is separately evaluated on an annual
basis for purposes of providing the management report that is set forth below.
Based on the controls evaluation, our CEO and CFO have concluded that, as of the end of the year covered by this 2022
Annual Report, our Disclosure Controls were effective to provide reasonable assurance that information required to be
disclosed in our Exchange Act reports is recorded, processed, summarized, and reported within the time periods specified
by the SEC, and the material information related to Argan and its consolidated subsidiaries is made known to management,
including the CEO and CFO, particularly during the period when our periodic reports are being prepared.
Management’s Report on Internal Control over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting to
provide reasonable assurance regarding the reliability of our financial reporting and the preparation of financial statements
for external purposes in accordance with U.S. GAAP. Internal control over financial reporting includes those policies and
procedures that (i) pertain to the maintenance of records that in reasonable detail accurately and fairly reflect the
transactions and dispositions of the assets of the Company; (ii) provide reasonable assurance that transactions are recorded
as necessary to permit preparation of financial statements in accordance with authorizations of management and directors
of the Company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized
acquisition, use, or disposition of the Company’s assets that could have a material effect on the consolidated financial
statements.
Management assessed our internal control over financial reporting as of January 31, 2022, the end of the fiscal year, based
on assessment criteria established in the 2013 Internal Control—Integrated Framework issued by the Committee of
Sponsoring Organizations of the Treadway Commission. Management’s assessment included evaluation of elements such
as the design and operating effectiveness of key financial reporting controls, process documentation, accounting policies,
and our overall control environment.
Based on its assessment, management has concluded that our internal control over financial reporting was effective as of
the end of the fiscal year to provide reasonable assurance regarding the reliability of financial reporting and the preparation
of financial statements for external reporting purposes in accordance with U.S. GAAP. We reviewed the results of
management’s assessment with the audit committee of our board of directors. In addition, on a quarterly basis, we will
evaluate any changes to our internal control over financial reporting to determine if material change occurred.
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Table of Contents Attestation Report of the Independent Registered Public Accounting Firm
The effectiveness of our internal control over financial reporting as of January 31, 2022 has been audited by Grant Thornton
LLP, our independent registered public accounting firm, who also audited our consolidated financial statements included
in this 2022 Annual Report, as stated in their reports which appear with our accompanying consolidated financial
statements.
Changes in Internal Controls
No change in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange
Act) occurred during the fiscal quarter ended January 31, 2022 that has materially affected, or is reasonably likely to
materially affect, our internal control over financial reporting.
Inherent Limitations on Effectiveness of Controls
The Company’s management, including the CEO and CFO, does not expect that our Disclosure Controls or our internal
control over financial reporting will prevent or detect all errors and all fraud. A control system, no matter how well
designed and operated, can provide only reasonable, not absolute, assurance that the control system’s objectives will be
met. The design of a control system must reflect the fact that there are resource constraints, and the benefits of controls
must be considered relative to their costs. Further, because of the inherent limitations in all control systems, no evaluation
of controls can provide absolute assurance that misstatements due to error or fraud will not occur or that all control issues
and instances of fraud, if any, within the Company have been detected. These inherent limitations include the realities that
judgments in decision-making can be faulty and that breakdowns can occur because of simple error or mistake. Controls
can also be circumvented by the individual acts of some persons, by collusion of two or more people, or by management
override of the controls.
The design of any system of controls is based in part on certain assumptions about the likelihood of future events, and
there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions.
Projections of any evaluation of controls effectiveness to future periods are subject to risks. Over time, controls may
become inadequate because of changes in conditions or deterioration in the degree of compliance with policies or
procedures.
ITEM 9B. OTHER INFORMATION.
Not Applicable.
PART III
The information required by the items of the 2022 Annual Report, Part III, that are identified below will be incorporated
by reference to our 2022 Proxy Statement relating to the election of directors and other matters, which is expected to be
filed by us pursuant to Regulation 14A, within 120 days after the close of our fiscal year.
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE.
ITEM 11. EXECUTIVE COMPENSATION.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT, AND
RELATED STOCKHOLDER MATTERS.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR
INDEPENDENCE.
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES.
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Table of Contents
ITEM 15. EXHIBITS AND FINANCIAL STATEMENTS.
The following exhibits are filed as part of this 2022 Annual Report:
PART IV
Exhibit
No.
3.1
3.2
Certificate of Incorporation, as amended. Incorporated by reference to Exhibit 3.1 to the
Registrant’s Annual Report on Form 10-K filed on April 10, 2019.
Bylaws. Incorporated by reference to Exhibit 3.2 to the Registrant’s Annual Report on Form 10-K
filed on April 15, 2009.
Description
4
Description of Registrant’s Securities. Incorporated by reference to Exhibit 4 to the Registrant’s
Annual Report on Form 10-K filed on April 14, 2020.
10.1
10.2
10.3
10.4
10.5
10.6
10.7
10.8
10.9
10.10
Argan, Inc. 2011 Stock Plan (Revised as of 4-10-18). Incorporated by reference to the Registrant’s
Proxy Statement filed on Schedule 14A on May 7, 2018.
Argan, Inc. 2020 Stock Plan. Incorporated by reference to the Registrant’s Proxy Statement filed on
Schedule 14A on May 6, 2020.
Employment Agreement dated as of January 3, 2005 by and between Argan, Inc. and Rainer H.
Bosselmann. Incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form
8-K filed on January 5, 2005.
Employment Agreement dated as of October 13, 2015 by and between Argan, Inc. and David H.
Watson. Incorporated by reference to Exhibit 10.1 to the Registrant’s Quarterly Report on Form 10-
Q filed on December 10, 2015.
Third Amended and Restated Employment Agreement, dated November 15, 2019, by and among
Gemma Power Systems, LLC, Gemma Power, Inc., Gemma Power Systems California, Inc.,
Gemma Power Hartford, LLC, Gemma Renewable Power, LLC, Gemma Power Operations, LLC
and William F. Griffin, Jr. Incorporated by reference to Exhibit 10.1 to the Registrant’s Quarterly
Report on Form 10-Q filed on December 10, 2019.
Employment Agreement, dated November 15, 2019, by and among Gemma Power Systems, LLC,
Gemma Power, Inc., Gemma Power Systems California, Inc., Gemma Power Hartford, LLC,
Gemma Renewable Power, LLC, Gemma Power Operations, LLC and Charles Collins IV.
Incorporated by reference to Exhibit 10.2 to the Registrant’s Quarterly Report on Form 10-Q filed
on December 10, 2019.
Employment Agreement, dated November 15, 2019, by and among Gemma Power Systems, LLC,
Gemma Power, Inc., Gemma Power Systems California, Inc., Gemma Power Hartford, LLC,
Gemma Renewable Power, LLC, Gemma Power Operations, LLC and Terrence Trebilcock.
Incorporated by reference to Exhibit 10.3 to the Registrant’s Quarterly Report on Form 10-Q filed
on December 10, 2019.
Amendment to Employment Agreement, dated February 1, 2022, by and among Gemma Power
Systems, LLC, Gemma Power, Inc., Gemma Power Systems California, Inc., Gemma Power
Hartford, LLC, Gemma Renewable Power, LLC, Gemma Power Operations, LLC and Terrence
Trebilcock.(a)
Replacement Credit Agreement, dated August 10, 2015, among Argan, Inc. (and certain
subsidiaries of Argan, Inc.) and Bank of America, N.A. Incorporated by reference to Exhibit 10.2
to the Registrant’s Quarterly Report on Form 10-Q filed on December 10, 2015.
First Amendment to Amended and Restated Replacement Credit Agreement, dated April 30, 2021,
among Argan, Inc. and certain subsidiaries of Argan, Inc., as borrowers, and Bank of America,
N.A., as the lender. Incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on
Form 8-K filed on April 30, 2021.
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Table of Contents
Exhibit
No.
10.11
10.12
14.1
14.2
21
23.1
31.1
31.2
32.1
32.2
Description
Deferred Compensation Plan, adopted by Gemma Power Systems, LLC, effective as of April 6,
2017. Incorporated by reference to Exhibit 10.7 of the Registrant’s Annual Report on Form 10-K
filed on April 11, 2017.
Amendment No. 2020-1 to the Gemma Power Systems, LLC Deferred Compensation Plan.
Incorporated by reference to Exhibit 10.1 to the Registrant’s Quarterly Report on Form 10-Q filed
on December 9, 2020.
Code of Ethics. Incorporated by reference to the Registrant’s Annual Report on Form 10-KSB filed
on April 27, 2004.
Argan, Inc. Code of Conduct, effective December 10, 2020. Incorporated by reference to Exhibit
14 to the Registrant’s Current Report on Form 8-K filed on December 10, 2020.
Subsidiaries of the Company. Incorporated by reference to Exhibit 21 to the Registrant’s Annual
Report on Form 10-K filed on April 14, 2021.
Consent of Grant Thornton LLP, Independent Registered Public Accounting Firm. (a)
Certification of CEO required by Section 302 of the Sarbanes-Oxley Act of 2002. (a)
Certification of CFO required by Section 302 of the Sarbanes-Oxley Act of 2002. (a)
Certification of CEO required by Section 906 of the Sarbanes-Oxley Act of 2002. (a)
Certification of CFO required by Section 906 of the Sarbanes-Oxley Act of 2002. (a)
101.INS
101.SCH
101.CAL
101.LAB
101.PRE
101.DEF
104
XBRL Instance Document – the instance document does not appear in the Interactive Data File
because its XBRL tags are embedded within the Inline XBRL document.
Inline XBRL Taxonomy Extension Schema.
Inline XBRL Taxonomy Extension Calculation Linkbase.
Inline XBRL Taxonomy Label Linkbase.
Inline XBRL Taxonomy Presentation Linkbase.
Inline XBRLTaxonomy Extension Definition Document.
Cover Page Interactive Data File (formatted as Inline XBRL with applicable taxonomy extension
information contained in Exhibits 101).
(a) Filed herewith.
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Table of Contents
In accordance with Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report
to be signed on its behalf by the undersigned, thereunto duly authorized.
SIGNATURES
April 13, 2022
ARGAN, INC.
By: /s/ David H. Watson
David H. Watson
Senior Vice President, Chief Financial Officer,
Treasurer and Secretary
(Principal Accounting and Financial Officer)
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following
persons on behalf of the Registrant and in the capacities and on the dates indicated.
Name
Title
Date
/s/ Rainer H. Bosselmann
Rainer H. Bosselmann
/s/ Cynthia A. Flanders
Cynthia A. Flanders
/s/ Peter W. Getsinger
Peter W. Getsinger
/s/ William F. Griffin
William F. Griffin
/s/ John R. Jeffrey
John R. Jeffrey
/s/ Mano Koilpillai
Mano Koilpillai
Chairman of the Board and Chief
Executive Officer
(Principal Executive Officer)
Director
Director
Director
Director
Director
/s/ William F. Leimkuhler
William F. Leimkuhler
Director
/s/ W. G. Champion Mitchell
W. G. Champion Mitchell
Director
/s/ James W. Quinn
James W. Quinn
Director
April 13, 2022
April 13, 2022
April 13, 2022
April 13, 2022
April 13, 2022
April 13, 2022
April 13, 2022
April 13, 2022
April 13, 2022
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Table of Contents
ARGAN, INC. AND SUBSIDIARIES
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
JANUARY 31, 2022
The following financial statements (including the notes thereto and the Reports of Independent Registered Public
Accounting Firm with respect thereto), are filed as part of this 2022 Annual Report.
Reports of Grant Thornton LLP, Independent Registered Public Accounting Firm (PCAOB ID Number 248)
Consolidated Statements of Earnings for the years ended January 31, 2022, 2021 and 2020
Consolidated Balance Sheets as of January 31, 2022 and 2021
Consolidated Statements of Stockholders’ Equity for the years ended January 31, 2022, 2021 and 2020
Consolidated Statements of Cash Flows for the years ended January 31, 2022, 2021 and 2020
Notes to Consolidated Financial Statements
Page
Number
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Table of Contents
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
Board of Directors and Stockholders
Argan, Inc.
Opinion on the financial statements
We have audited the accompanying consolidated balance sheets of Argan, Inc. (a Delaware corporation) and subsidiaries
(the “Company”) as of January 31, 2022 and 2021, the related consolidated statements of earnings, changes in
stockholders’ equity, and cash flows for each of the three years in the period ended January 31, 2022, and the related notes
(collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material
respects, the financial position of the Company as of January 31, 2022 and 2021, and the results of its operations and its
cash flows for each of the three years in the period ended January 31, 2022, in conformity with accounting principles
generally accepted in the United States of America.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United
States) (“PCAOB”), the Company’s internal control over financial reporting as of January 31, 2022, based on criteria
established in the 2013 Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations
of the Treadway Commission (“COSO”), and our report dated April 13, 2022 expressed an unqualified opinion.
Basis for opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion
on the Company’s financial statements based on our audits. We are a public accounting firm registered with the 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 audit to obtain reasonable assurance about whether the financial statements are free of material misstatement,
whether due to error or fraud. Our audits 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. We believe that our audits provide a reasonable basis for
our opinion.
Critical audit matter
The critical audit matter communicated below is a matter arising from the current period audit of the financial statements
that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or
disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex
judgments. The communication of the critical audit matter does not alter in any way our opinion on the financial statements,
taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the
critical audit matter or on the accounts or disclosures to which it relates.
Revenue recognition for fixed-price contracts
As described in Note 4 to the consolidated financial statements, the Company recognizes revenues for fixed-price contracts
over time using an input method described as the cost-to-cost approach to determine the extent of progress towards
completion of performance obligations and an estimate of total contract revenues. Under the cost-to-cost approach, the
determination of the progress towards completion requires management to prepare estimates of the costs to complete.
These estimates are subject to considerable judgment and could be impacted by such items as changes to the project
schedule and scope and the cost of labor, materials, and subcontractors.
The principal consideration for our determination that revenue recognition for fixed-price contracts is a critical audit matter
is that auditing management’s estimate of total contract revenues and projected costs on fixed-price contracts was complex
and subjective. Considerable auditor judgment was required in evaluating management’s determination of the costs
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Table of Contents estimated to complete the related performance obligations as future results may vary significantly from past estimates due
to changes in facts and circumstances.
Our audit procedures related to the auditing of fixed-price contract revenues included, among others:
• We evaluated the design and tested the operating effectiveness of internal controls over the estimation process
that affects revenues recognized on fixed-price contracts, including key controls related to monitoring projected
contract costs and profit estimates.
• For a sample of fixed-price contracts we assessed the appropriate application of revenue recognition using the
cost-to-cost method, evaluated the significant assumptions which were used to develop the estimates-to-complete,
and tested the completeness and accuracy of the underlying data.
• We conducted interviews with project personnel, attended a sample of monthly project review meetings, visited
the worksite of a significant project, obtained supporting documentation for estimates of project contingencies,
and performed lookback analyses comparing actual costs incurred to prior estimates-to-complete to assess
management’s ability to estimate future costs.
/s/ GRANT THORNTON LLP
We have served as the Company’s auditor since 2007.
Arlington, Virginia
April 13, 2022
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Table of Contents
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
Board of Directors and Stockholders
Argan, Inc.
Opinion on internal control over financial reporting
We have audited the internal control over financial reporting of Argan, Inc. (a Delaware corporation) and subsidiaries (the
“Company”) as of January 31, 2022, based on criteria established in the 2013 Internal Control—Integrated Framework
issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”). In our opinion, the
Company maintained, in all material respects, effective internal control over financial reporting as of January 31, 2022,
based on criteria established in the 2013 Internal Control—Integrated Framework issued by COSO.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United
States) (“PCAOB”), the consolidated financial statements of the Company as of and for the year ended January 31, 2022,
and our report dated April 13, 2022 expressed an unqualified opinion on those financial statements.
Basis for opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its
assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s
Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal
control over financial reporting based on our audit. We are a public accounting firm registered with the 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 audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform
the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained
in all material respects. Our audit included obtaining an understanding of internal control over financial reporting,
assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal
control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances.
We believe that our audit provides a reasonable basis for our opinion.
Definition and limitations of internal control over financial reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the
reliability of financial reporting and the preparation of financial statements for external purposes in accordance with
generally accepted accounting principles. A company’s internal control over financial reporting includes those policies
and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the
transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded
as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles,
and that receipts and expenditures of the company are being made only in accordance with authorizations of management
and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of
unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial
statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also,
projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate
because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ GRANT THORNTON LLP
Arlington, Virginia
April 13, 2022
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Table of Contents
ARGAN, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF EARNINGS
FOR THE YEARS ENDED JANUARY 31,
(In thousands, except per share data)
REVENUES
Cost of revenues
GROSS PROFIT (LOSS)
Selling, general and administrative expenses
Impairment losses
INCOME (LOSS) FROM OPERATIONS
Other income, net
INCOME (LOSS) BEFORE INCOME TAXES
Income tax (expense) benefit
NET INCOME (LOSS)
Net (loss) income attributable to non-controlling interests
NET INCOME (LOSS) ATTRIBUTABLE TO THE STOCKHOLDERS OF
ARGAN, INC.
Foreign currency translation adjustments
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO THE
STOCKHOLDERS OF ARGAN, INC.
NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO THE
STOCKHOLDERS OF ARGAN, INC.
Basic
Diluted
WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING
Basic
Diluted
2022
2020
2021
$ 509,370 $ 392,206 $ 238,997
245,817
330,139
409,638
(6,820)
62,067
99,732
44,125
39,041
47,321
4,895
—
7,901
(55,840)
23,026
44,510
8,075
1,859
2,552
(47,765)
24,885
47,062
7,053
(1,074)
(11,356)
(40,712)
23,811
35,706
1,977
(40)
(2,538)
38,244
(1,370)
23,851
35
(42,689)
(770)
$ 36,874 $ 23,886 $ (43,459)
$
$
2.43 $
2.40 $
1.52 $
1.51 $
(2.73)
(2.73)
15,715
15,913
15,668
15,825
15,621
15,621
CASH DIVIDENDS PER SHARE
$
1.00 $
3.00 $
1.00
The accompanying notes are an integral part of these consolidated financial statements.
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Table of Contents
ARGAN, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
JANUARY 31,
(Dollars in thousands, except per share data)
2022
2021
ASSETS
CURRENT ASSETS
Cash and cash equivalents
Short-term investments
Accounts receivable, net
Contract assets
Other current assets
TOTAL CURRENT ASSETS
Property, plant and equipment, net
Goodwill
Other purchased intangible assets, net
Deferred taxes, net
Right-of-use and other assets
TOTAL ASSETS
LIABILITIES AND EQUITY
CURRENT LIABILITIES
Accounts payable
Accrued expenses
Contract liabilities
TOTAL CURRENT LIABILITIES
Other noncurrent liabilities
TOTAL LIABILITIES
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS’ EQUITY
$ 350,472 $ 366,671
90,055
28,713
26,635
34,146
546,220
20,361
27,943
4,097
249
3,760
553,585 $ 602,630
90,026
26,978
4,904
34,904
507,284
10,460
28,033
3,322
457
4,029
$
$
41,822 $
53,315
127,890
223,027
4,963
227,990
53,295
50,750
172,042
276,087
4,135
280,222
Preferred stock, par value $0.10 per share – 500,000 shares authorized; no shares issued
and outstanding
Common stock, par value $0.15 per share – 30,000,000 shares authorized; 15,788,673
and 15,706,202 shares issued at January 31, 2022 and 2021, respectively; 15,257,688
and 15,702,969 shares outstanding at January 31, 2022 and 2021, respectively
Additional paid-in capital
Retained earnings
Less treasury stock, at cost – 530,985 and 3,233 shares at January 31, 2022 and 2021,
respectively
Accumulated other comprehensive loss
TOTAL STOCKHOLDERS’ EQUITY
Non-controlling interests
TOTAL EQUITY
TOTAL LIABILITIES AND EQUITY
—
—
2,368
158,190
188,690
2,356
153,315
166,110
(20,405)
(2,451)
326,392
(797)
325,595
(33)
(1,081)
320,667
1,741
322,408
$ 553,585 $ 602,630
The accompanying notes are an integral part of these consolidated financial statements.
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Table of Contents
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3
6
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3
6
-
Table of Contents Table of Contents
ARGAN, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
FOR THE YEARS ENDED JANUARY 31,
(Dollars in thousands)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)
Adjustments to reconcile net income (loss) to net cash provided by operating
activities
Impairment losses
Stock compensation expense
Lease expense
Provisions for credit losses
Depreciation
Amortization of purchased intangible assets
Deferred income tax (benefit) expense
Other
Changes in operating assets and liabilities
Accounts receivable
Contract assets
Other assets
Accounts payable and accrued expenses
Contract liabilities
Net cash provided by operating activities
CASH FLOWS FROM INVESTING ACTIVITIES
Maturities of short-term investments
Purchases of short-term investments
Investments in solar energy projects
Purchases of property, plant and equipment
Acquisition of Lee Telecom, Inc.
Net cash (used in) provided by investing activities
CASH FLOWS FROM FINANCING ACTIVITIES
Payments of cash dividends
Common stock repurchases
Proceeds from the exercise of stock options
Net cash used in financing activities
EFFECTS OF EXCHANGE RATE CHANGES ON CASH
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD
CASH AND CASH EQUIVALENTS, END OF PERIOD
SUPPLEMENTAL CASH FLOW INFORMATION (see Notes 10 and 13)
2022
2021
2020
$ 35,706 $
23,811 $ (40,712)
7,901
3,459
3,391
2,381
3,367
870
(208)
424
—
2,938
1,820
16
3,715
904
7,645
625
(480)
21,741
(241)
(5,742)
(44,154)
28,415
8,463
6,744
(11,467)
31,442
99,357
176,013
4,895
2,131
1,004
20
3,513
1,136
(6,640)
869
(1,038)
24,978
2,357
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64,336
53,565
90,000
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(5,016)
(1,422)
(600)
(7,038)
170,000
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(1,333)
(1,697)
—
66,970
166,000
(195,000)
—
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(15,664)
(20,372)
1,428
(34,608)
(47,047)
—
1,641
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(15,621)
—
1,630
(13,991)
(2,968)
(16,199)
366,671
(471)
3,045
164,318
$ 350,472 $ 366,671 $ 167,363
1,731
199,308
167,363
The accompanying notes are an integral part of these consolidated financial statements.
- 64 -
- 64 -
Table of Contents
ARGAN, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JANUARY 31, 2022, 2021 AND 2020
(Tabular amounts in thousands, except per share data)
NOTE 1 – DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION
Description of the Business
Argan, Inc. (“Argan”) conducts operations through its wholly owned subsidiaries, Gemma Power Systems, LLC and
affiliates (“GPS”); The Roberts Company, Inc. (“TRC”); Atlantic Projects Company Limited and affiliates (“APC”) and
Southern Maryland Cable, Inc. (“SMC”). Argan and these consolidated subsidiaries are hereinafter collectively referred
to as the “Company.”
Through GPS and APC, the Company provides a full range of engineering, procurement, construction, commissioning,
operations management, maintenance, project development, technical and other consulting services to the power
generation market, including the renewable energy sector. The wide range of customers includes independent power
producers, public utilities, power plant equipment suppliers and global energy plant construction firms with projects
located in the continental United States (the “U.S.”), the Republic of Ireland (“Ireland”) and the United Kingdom (the
“U.K.”). Including a consolidated variable interest entity (“VIE”), GPS and APC represent the Company’s power industry
services reportable segment. Through TRC, the industrial fabrication and field services reportable segment provides on-
site services that support maintenance turnarounds, shutdowns and emergency mobilizations for industrial plants primarily
located in the southeast region of the U.S. and that are based on its expertise in producing, delivering and installing
fabricated metal components such as piping systems and pressure vessels. Through SMC, which conducts business as
SMC Infrastructure Solutions, the telecommunications infrastructure services segment provides project management,
construction, installation and maintenance services to commercial, local government and federal government customers
primarily in the Mid-Atlantic region of the U.S.
Basis of Presentation and Significant Accounting Policies
The consolidated financial statements include the accounts of Argan, its wholly owned subsidiaries, and its controlled VIE
(see Note 3). All significant inter-company balances and transactions have been eliminated in consolidation. In Note 17,
the Company has provided certain financial information relating to the operating results and assets of its reportable
segments based on the manner in which management disaggregates the Company’s financial reporting for purposes of
making internal operating decisions. The Company’s fiscal year ends on January 31 of each year.
Use of Estimates – The preparation of consolidated financial statements in conformity with accounting principles generally
accepted in the United States of America (“U.S. GAAP”) requires management to make estimates and assumptions that
affect the reported amounts of assets and liabilities, revenues, expenses, and certain financial statement disclosures.
Management believes that the estimates, judgments and assumptions upon which it relies are reasonable based upon
information available to it at the time that these estimates, judgments and assumptions are made. Estimates are used for,
but are not limited to, the Company’s accounting for revenues, the valuation of assets with long and indefinite lives
including goodwill, the valuation of restricted stock units and options to purchase shares of the Company’s common stock,
the evaluation of contingent obligations and uncertain income tax return positions, the valuation of deferred taxes, and the
determination of the allowance for doubtful accounts. Actual results could differ from these estimates.
Property, Plant and Equipment – Property, plant and equipment are stated at cost less accumulated depreciation. Such
assets acquired in a business combination are initially included in the Company’s consolidated balance sheet at fair values.
The Company capitalizes the power plant project development costs incurred by its consolidated variable interest entities.
Should these construction preparation efforts be unsuccessful, the costs would be written-off at that time. Depreciation
amounts are determined using the straight-line method over the estimated useful lives of the assets, other than land, which
are generally from five to thirty-nine years. Building and leasehold improvements are amortized on a straight-line basis
over the shorter of the estimated useful life of the related asset or the lease term, as applicable. The costs of maintenance
and repairs are expensed as incurred and major improvements are capitalized. When an asset is sold or retired, the cost
and related accumulated depreciation amounts are removed from the accounts and the resulting gain or loss is included in
earnings.
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Table of Contents
Goodwill – On November 1 of each year, the Company reviews the carrying value of goodwill amounts for impairment.
Each goodwill impairment assessment is performed using the quantitative business valuation process except in those
circumstances when a qualitative approach performed by management results in a conclusion that it is unlikely that an
impairment of the applicable goodwill amount has occurred. The Company also evaluates amounts of goodwill for
impairment at any time when events or changes in circumstances indicate that goodwill value may be impaired.
The Company identifies a potential impairment loss by comparing the fair value of a reporting unit with the reporting
unit’s carrying amount, including goodwill. In the quantitative approach, the fair value of the reporting unit is estimated
using various market-based and income-based valuation techniques as applicable in the particular circumstances. If the
fair value of the reporting unit exceeds the related carrying amount, goodwill of the reporting unit is not deemed to be
impaired. If the carrying amount of the reporting unit exceeds its fair value, a goodwill impairment loss is recorded in an
amount equal to the excess of the unit’s carrying value over its fair value, not to exceed the amount of goodwill allocated
to the reporting unit.
An alternative method allows the Company to first assess qualitative factors to decide whether it is necessary to perform
the quantitative goodwill impairment test. It is not required to calculate the fair value of a reporting unit unless management
concludes, based on a qualitative assessment, that it is more likely than not that its fair value may be less than the
corresponding carrying amount. The professional guidance for this evaluation identifies the types of factors which the
Company should consider in conducting the qualitative assessment including macroeconomic, industry, market and entity-
specific factors.
Long-Lived Assets – Long-lived assets (other than goodwill), consisting primarily of purchased intangible assets with
definite lives, property, plant and equipment, are subject to review for impairment whenever events or changes in
circumstances indicate that a carrying amount should be assessed. In such circumstances, the Company would compare
the carrying value of the long-lived asset to the undiscounted future cash flows expected to result from the use of the asset.
In the event that the Company would determine that the carrying value of the asset is not recoverable, a loss would be
recognized based on the amount by which the carrying value exceeds the fair value of the asset. Fair value would be
determined by using quoted market prices or valuation techniques such as the present value of expected future cash flows,
appraisals, or other pricing models as appropriate. The useful lives and amortization of purchased intangible assets are
described in Note 7.
Revenue Recognition – The Company’s accounting for revenues on contracts with customers is based on a single
comprehensive five-step model that requires reporting entities to:
Identify the contract,
Identify the performance obligations of the contract,
1.
2.
3. Determine the transaction price of the contract,
4. Allocate the transaction price to the performance obligations, and
5. Recognize revenue.
The Company focuses on the transfer of the contractor’s control of the goods and/or services to the customer, as opposed
to the transfer of risk and rewards. Major provisions of the current guidance cover the determination of which goods and
services are distinct and represent separate performance obligations, the appropriate treatments for variable consideration,
and the evaluation of whether revenues should be recognized at a point in time or over time.
When a performance obligation is satisfied over time, the related revenues are recognized over time. The Company’s
revenues are recognized primarily under various types of long-term construction contracts, including those for which
revenues are based on either a fixed-price or a time-and-materials basis, and primarily over time as performance obligations
are satisfied due to the continuous transfer of control to the project owner or other customer.
Revenues from fixed-price contracts, including portions of estimated gross profit, are recognized as services are provided,
based on costs incurred and estimated total contract costs using the cost-to-cost approach. If, at any time, the estimate of
contract profitability indicates an anticipated loss on a contract, the Company will recognize the total loss in the reporting
period in which it is identified and the loss amount becomes estimable. Revenues from time-and-materials contracts are
recognized when the related services are provided to the customer.
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Table of Contents Almost all of the Company’s fixed-price contracts are considered to have a single performance obligation. Although
multiple promises to transfer individual goods or services may exist, they are not typically distinct within the context of
such contracts because contract promises included therein are interrelated or the contracts require the Company to perform
critical integration so that the customer receives a completed project. Warranties provided under the Company’s contracts
with customers are assurance-type primarily and are recorded as the corresponding contract work is performed.
The transaction price for a contract represents the value of the contract awarded to the Company that is used to determine
the amount of revenues recognized as of the balance sheet date. It may reflect amounts of variable consideration which
could be either increases or decreases to the transaction price. These adjustments can be made from time-to-time during
the period of contract performance as circumstances evolve related to such items as changes in the scope and price of
contracts, claims, incentives and liquidated damages.
Contract assets include amounts that represent the rights to receive payment for goods or services that have been transferred
to the project owner, with the rights conditional upon something other than the passage of time. Contract liabilities include
amounts that reflect obligations to provide goods or services for which payment has been received. Contract retentions are
billed amounts which, pursuant to the terms of the applicable contract, are not paid by project owners until a defined phase
of a contract or project has been completed and accepted. These retained amounts are reflected in contract assets or contract
liabilities depending on the net contract position of the particular contract. Retention amounts and the length of retention
periods may vary. Retainage amounts related to active contracts are considered current regardless of the term of the
applicable contract; such amounts are generally collected by the completion of the applicable contract. The total of amounts
retained by project owners under construction contracts at January 31, 2022, and 2021 were $40.4 million and $36.8
million, respectively.
Income Taxes – Deferred taxes are recognized using enacted tax rates for the effects of temporary differences between the
book and tax bases of assets and liabilities. If management believes that it is more likely than not that some portion or all
of a deferred tax asset will not be realized, the carrying value will be reduced by a valuation allowance.
The Company accounts for uncertain tax positions in accordance with current accounting guidance which prescribes a
recognition threshold and measurement attribute for financial statement disclosure of tax positions taken, or expected to
be taken, on the income tax returns of the Company. Management evaluates and the Company records the effect of any
uncertain tax position based on the amount that management deems is more likely than not (i.e., greater than a 50%
probability) to be sustained upon examination and ultimate settlement with the tax authorities in the applicable tax
jurisdiction.
Interest incurred related to overdue income taxes is included in income tax expense; franchise taxes and income tax
penalties are included in selling, general and administrative expenses.
Share-Based Payments – The Company measures and recognizes compensation expense for all stock-based awards granted
to employees and directors based upon estimates of fair value determined at the dates of award using an option pricing
model. The compensation expense for each stock option is recognized on a straight-line basis over the corresponding
vesting period which is typically three years. The fair value amounts associated with restricted stock unit awards, which
are determined on the dates of award, are being recorded in stock compensation expense over the three-year contractual
lapsing periods for the corresponding restrictions. For each exercise of a stock option or each vesting of a restricted stock
unit, the Company determines whether the difference between the deduction for income tax reporting purposes created at
that time and the related compensation expense previously recorded for financial reporting purposes results in either an
excess income tax benefit or an income tax deficiency which is recognized, accordingly, as income tax benefit or expense
in the corresponding consolidated statement of earnings.
Fair Values – Current professional accounting guidance applies to all assets and liabilities that are being measured and
reported on a fair value basis. Fair value is defined as the price that would be received to sell an asset or paid to transfer a
liability in an orderly transaction between market participants at the measurement date in the principal or most
advantageous market. The carrying value amounts presented in the consolidated balance sheets for the Company’s current
assets, which primarily include cash and cash equivalents, short-term investments, accounts receivable and contract assets,
and its current liabilities are reasonable estimates of their fair values due to the short-term nature of these items.
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Table of Contents The fair value amounts of reporting units (as needed for purposes of identifying goodwill impairment losses) are
determined by averaging valuations that are calculated using market-based and income-based approaches deemed
appropriate in the circumstances.
Foreign Currency Translation – The accompanying consolidated financial statements are presented in the currency of the
United States (“U.S. Dollars”). The effects of translating the financial statements of APC from its functional currency
(Euros) into the Company’s reporting currency (U.S. Dollars) are recognized as translation adjustments in accumulated
other comprehensive loss. There are no applicable income taxes. The translation of assets and liabilities to U.S. Dollars is
made at the exchange rate in effect at the consolidated balance sheet date, while equity accounts are translated at historical
rates. The translation of the statement of earnings amounts is made monthly based generally on the average currency
exchange rate for the month. Net foreign currency transaction gains and losses are included in other income, net, in the
consolidated statements of earnings. For the years ended January 31, 2022 (Fiscal 2022”), 2021 (“Fiscal 2021”) and 2020
(Fiscal 2020”), such amounts were not material.
NOTE 2 – RECENTLY ISSUED ACCOUNTING PRONOUNCEMENTS
In December 2019, the Financial Accounting Standards Board issued Accounting Standards Update 2019-12, Simplifying
the Accounting for Income Taxes, which, among other changes, eliminates the exception to the general methodology for
calculating income taxes in an interim period when a year-to-date loss exceeds the expected loss for the entire year. In
these instances, the estimated annual effective income tax rate shall be used to calculate the tax without limitation. The
new standard also requires the recognition of a franchise (or similar) tax that is partially based on income as an income-
based tax and the recording of any incremental tax that is incurred by the Company as a non-income based tax. The
Company’s adoption of this new guidance, which was effective on February 1, 2021, did not alter the Company’s
accounting for income taxes. There are no other recently issued accounting pronouncements that have not yet been adopted
that the Company considers material to its consolidated financial statements.
NOTE 3 – SPECIAL PURPOSE ENTITIES
Variable Interest Entity
In January 2018, the Company was deemed to be the primary beneficiary of a VIE that is performing the project
development activities related to the planned construction of a new natural gas-fired power plant. Consequently, the
account balances of the VIE are included in the Company’s consolidated financial statements, including development costs
incurred by the VIE during the project development period. The total amount of the project development costs included in
the balances for property, plant and equipment was $7.5 million as of January 31, 2021. Consideration for the Company’s
engineering and financial support provided to the project included the right to build the power plant pursuant to a turnkey
engineering, procurement and construction (“EPC”) services contract that was negotiated and announced.
GPS provided financing for the development efforts through notes receivable from the consolidated VIE that was
established by the project owner. GPS also provided technical support to the project. Significant development milestones
were achieved by the project owner. However, a planned gas pipeline expansion that the project owner believed would
supply natural gas to the power plant was rejected by Virginia’s State Corporation Commission during Fiscal 2022, which
led to cancellation by PJM Interconnection LLC (“PJM”) of its interconnection service agreement with the project based
on alleged failures of the project to meet required milestones. In February 2022, PJM, which operates the electricity grid
in the region, received notice from the Federal Energy Regulatory Commission accepting PJM’s termination of the service
agreement which effectively removed the Chickahominy Power Station from PJM’s planning queue.
In summary, the project owner was unable to secure an alternative fuel-supply for the plant and the project lost its
interconnection service commitment from PJM. Therefore, the project owner was unable to obtain the necessary equity
financing for the project and GPS ceased providing project development funding. The repayment of the notes to GPS is
overdue and the VIE has rejected the Company’s efforts to foreclose on the defaulted debt in an orderly fashion.
Accordingly, the Company now believes that the completion of the development of this project has been significantly
jeopardized and that it is doubtful that construction of this power plant will occur. Accordingly, during the fourth quarter
of Fiscal 2022, we recorded an impairment loss related to the capitalized project development costs of this project in the
amount of $7.9 million, of which $2.5 million was attributed to the non-controlling interest. In March 2022, the project
owner publicly announced the cancellation of this power plant project.
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Table of Contents NOTE 4 – REVENUES FROM CONTRACTS WITH CUSTOMERS
Variable Consideration
Amounts for contract variations for which the Company has project-owner directive for additional work or other scope
change, but not for the price associated with the corresponding additional effort, are included in the transaction price when
it is considered probable that the applicable costs will be recovered through a modification to the contract price. The effects
of any revision to a transaction price can be determined at any time and they could be material. The Company may include
in the corresponding transaction price a portion of the amount claimed in a dispute that it expects to receive from a project
owner. Once a settlement of the dispute has been reached with the project owner, the transaction price may be revised
again to reflect the final resolution. The aggregate amount of such contract variations included in the transaction prices
that were used to determine project-to-date revenues at January 31, 2022 and 2021, were $7.5 million and $16.6 million,
respectively. Variations related to the Company’s contracts typically represent modifications to the existing contracts and
performance obligations, and do not represent new performance obligations. Actual costs related to any changes in the
scope of the corresponding contract are expensed as they are incurred. Changes to total estimated contract costs and losses,
if any, are reflected in operating results for the period in which they are determined.
The Company’s long-term contracts typically have schedule dates and other performance objectives that if not achieved
could subject the Company to liquidated damages. These contract requirements generally relate to specified activities that
must be completed by an established date or by the achievement of a specified level of output or efficiency. Each applicable
contract defines the conditions under which a project owner may be entitled to any liquidated damages. At the outset of
each of the Company’s contracts, the potential amounts of liquidated damages typically are not subtracted from the
transaction price as the Company believes that it has included activities in its contract plan, and the associated costs, that
will be effective in preventing such damages. Of course, circumstances may change as the Company executes the
corresponding contract. The transaction price is reduced by an applicable amount when the Company no longer considers
it probable that a future reversal of revenues will not occur when the matter is resolved. The Company considers potential
liquidated damages, the costs of other related items and potential mitigating factors in determining the adequacy of its
regularly updated estimates of the amounts of gross profit expected to be earned on active projects.
In other cases, the Company may have the grounds to assert liquidated damages against subcontractors, suppliers, project
owners or other parties related to a project. Such circumstances may arise when the Company’s activities and progress are
adversely affected by delayed or damaged materials, challenges with equipment performance or other events out of the
Company’s control where the Company has rights to recourse, typically in the form of liquidated damages. In general, the
Company does not adjust the corresponding contract accounting until it is probable that the favorable cost relief will be
realized. Such adjustments have been and could be material.
The Company records adjustments to revenues and profits on contracts, including those associated with contract variations
and estimated cost changes, using a cumulative catch-up method. Under this method, the impact of an adjustment to the
amount of revenues recognized to date is recorded in the period that the adjustment is identified. Estimated variable
consideration amounts are determined by the Company based primarily on the single most likely amount in the range of
possible consideration amounts. Revenues and profits in future periods of contract performance are recognized using the
adjusted amounts of transaction price and estimated contract costs.
Accounting for the Subcontract Loss
For Fiscal 2020, the Company recorded a loss in the amount of $33.6 million related to a subcontract project covering
construction activities that were performed by APC on the mechanical installation of the boiler for a biomass-fired power
plant under construction in Teesside, England, the Tees Renewable Energy Plant (“TeesREP”).
Completion of the works for the subcontract, as amended during Fiscal 2021, resulted in a reduction to the loss in the
approximate amount of $4.1 million. Accordingly, the final amount of the TeesREP subcontract loss was $29.5 million,
and the remaining subcontract loss reserve balance was eliminated as of January 31, 2021.
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Table of Contents Remaining Unsatisfied Performance Obligations (“RUPO”)
The amount of RUPO represents the unrecognized revenue value of active contracts with customers as determined under
the revenue recognition rules of U.S. GAAP. Increases to RUPO during a reporting period represent the transaction prices
associated with new contracts, as well as additions to the transaction prices of existing contracts. The amounts of such
changes may vary significantly each reporting period based on the timing of major new contract awards and the occurrence
and assessment of contract variations.
At January 31, 2022, the Company had RUPO of $397.0 million. The largest portion of RUPO at any date usually relates
to EPC service contracts with typical performance durations of one to three years. However, the length of certain significant
construction projects may exceed three years. The Company estimates that approximately 84% of the RUPO amount at
January 31, 2022 will be included in the amount of consolidated revenues that will be recognized during Fiscal 2023. Most
of the remaining amount of the RUPO amount at January 31, 2022 is expected to be recognized in revenues during the
fiscal year ending January 31, 2024. Revenues for future periods will also include amounts related to customer contracts
started or awarded subsequent to January 31, 2022.
It is important to note that estimates may be changed in the future and that cancellations, deferrals, scope adjustments may
occur related to work included in the amount of RUPO at January 31, 2022. Accordingly, RUPO may be adjusted to reflect
project delays and cancellations, revisions to project scope and cost and foreign currency exchange fluctuations, or to
revise estimates, as effects become known. Such adjustments may materially reduce future revenues below Company
estimates.
Disaggregation of Revenues
The following table presents consolidated revenues for Fiscal 2022, Fiscal 2021 and Fiscal 2020, disaggregated by the
geographic area where the corresponding projects were located:
United States
Republic of Ireland
United Kingdom
Other
Consolidated Revenues
2022
2020
2021
$ 456,211 $ 340,615 $ 169,299
20,342
49,028
328
$ 509,370 $ 392,206 $ 238,997
13,638
37,836
117
35,044
17,521
594
The major portion of the Company’s consolidated revenues are recognized pursuant to fixed-price contracts with most of
the remaining portions earned pursuant to time-and-material contracts. Consolidated revenues are disaggregated by
reportable segment in Note 17 to the consolidated financial statements.
NOTE 5 – CASH, CASH EQUIVALENTS AND SHORT-TERM INVESTMENTS
At January 31, 2022 and 2021, significant amounts of cash equivalents were invested in government and prime money
market funds with net assets invested in high-quality money market instruments. Such investments include U.S. Treasury
obligations; obligations of U.S. government agencies, authorities, instrumentalities or sponsored enterprises; and
repurchase agreements secured by U.S. government obligations. Due to market conditions, returns on money market
instruments are currently minimal. The Company considers all liquid investments with original maturities of three months
or less at the time of purchase to be cash equivalents.
Short-term investments as of January 31, 2022 and 2021 consisted solely of certificates of deposit purchased from Bank
of America (the “Bank”) with weighted average initial maturities of less than one year (the “CDs” ). The Company has
the intent and ability to hold the CDs until they mature, and they are carried at cost plus accrued interest which
approximates fair value. Interest income is recorded when earned and is included in other income. At January 31, 2022
and 2021, the weighted average annual interest rates of the outstanding CDs were 0.1% and 0.2%, respectively.
The Company has a substantial portion of its cash on deposit in the U.S. with the Bank. The Company also maintains
certain Euro-based bank accounts in Ireland and certain pound sterling-based bank accounts in the U.K. in support of the
operations of APC. Management does not believe that the combined amount of the CD investments and the cash deposited
with the Bank and financial institutions in Ireland and the U.K., in excess of government-insured levels, represents a
material risk.
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Table of Contents
NOTE 6 – ACCOUNTS AND NOTES RECEIVABLE
The Company generally extends credit to a customer based on an evaluation of the customer’s financial condition without
requiring tangible collateral. Exposure to losses on accounts and notes receivable is expected to differ due to the varying
financial condition of each customer. The Company monitors its exposure to credit losses and may establish an allowance
for credit losses based on management’s estimate of the loss that is expected to occur over the remaining life of the
particular financial asset. For Fiscal 2022, the amount of the provision for credit losses expected by management was $2.4
million. The amounts of the provision for credit losses for Fiscal 2021 and Fiscal 2020 were insignificant. The allowance
for credit losses as of January 31, 2022 was $2.4 million. The amount of the allowance for credit losses as of January 31,
2021 was insignificant.
NOTE 7 – PURCHASED INTANGIBLE ASSETS
The balance of goodwill related to TRC and included in the consolidated balance sheets as of January 31, 2022 and 2021
was $9.5 million. The Company performed a goodwill impairment assessment for TRC as of November 1, 2021 with the
assistance of a professional business valuation firm. It was determined that the fair value of TRC exceeded the
corresponding carrying value by approximately $8.9 million; accordingly, there was no impairment loss recorded as of
that date. Although the Company believes that the forecasted financial results for TRC as of November 1, 2021 are
reasonable considering recent operating and current business prospects, any future results that would compare unfavorably
with the projected results could result in additional goodwill impairment losses. No events related to TRC occurred during
the fourth quarter of Fiscal 2022 that caused the Company to perform a subsequent impairment assessment.
The goodwill impairment assessment performed for TRC as of November 1, 2019 determined that the fair value of TRC
was less than the corresponding carrying value and goodwill impairment loss of approximately $2.8 million was recorded
during Fiscal 2020. The fair value amount for TRC reflected a weighting of results determined using various business
valuation approaches. The majority of the weighted average fair value amount determined was based on discounted future
net-after-tax cash flows of the business that were forecasted at the time.
Primarily due to the significant reduction of the fair value of the business of APC deemed to have occurred as a result of
the substantial subcontract loss discussed in Note 4 above which was considered to be an assessment triggering event, the
Company recorded an impairment loss during Fiscal 2020 in the amount of $2.1 million.
The Company used a qualitative approach to assess the goodwill of GPS as of November 1, 2021, 2020 and 2019. At each
date, the Company concluded that it was more likely than not that the fair value of the GPS reporting unit exceeded the
corresponding carrying value by a substantial margin. Therefore, completion of the quantitative impairment assessment
was considered to be unnecessary in each case.
During Fiscal 2022, SMC completed the acquisition of Lee Telecom, Inc. (“LTI”) which is located in Hampton, Virginia.
The acquisition represented a purchase of the assets of LTI, for which SMC paid $0.6 million cash, including customer
contracts and goodwill.
The changes in the balances of the Company’s goodwill for Fiscal 2022, Fiscal 2021 and Fiscal 2020 were as follows:
Balances, February 1, 2019
Impairment losses
Balances, January 31, 2020
Impairment losses
Balances, January 31, 2021
Impairment losses
Acquisition of LTI
Balances, January 31, 2022
TRC
SMC Totals
APC
GPS
$ 18,476 $ 12,290 $ 2,072 $ — $ 32,838
(4,895)
—
(2,072)
27,943
—
—
—
—
—
27,943
—
—
—
—
—
—
90
90
— $ 90 $ 28,033
(2,823)
9,467
—
9,467
—
—
—
18,476
—
18,476
—
—
$ 18,476 $ 9,467 $
The impairment losses recorded by the Company for TRC and APC since the fiscal year ended January 31, 2016, the year
that both companies were acquired, represents 34% of the goodwill amount originally established for TRC and 100% of
the original amount of goodwill related to APC.
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Table of Contents
For income tax reporting purposes, goodwill related to acquisitions in the approximate amount of $16.5 million is being
amortized on a straight-line basis over periods of 15 years. The other amounts of the Company’s goodwill are not
amortizable for income tax reporting purposes.
Purchased intangible assets, other than goodwill, consisted of the following elements as of January 31, 2022:
January 31,
2021, (net
Accumulated
Useful Life Amounts Amortization Amounts amounts)
January 31, 2022
Estimated
Gross
Net
Trade names
TRC
GPS
Process certifications
Customer relationships
Customer contracts
Totals
15 years $
15 years
7 years
10 years
< 1 year
4,499 $
3,643
1,897
916
95
$ 11,050 $
1,849 $
3,643
1,671
565
—
7,728 $
2,650 $
—
226
351
95
3,322 $
2,949
208
497
443
—
4,097
The Company determined the fair values of the trade names using a relief-from-royalty methodology. The Company
believes that the useful life of the trade name for TRC represents the remaining number of years that such intangible asset
is expected to contribute to future cash flows. In order to value the process certifications of TRC, the Company applied a
reproduction cost method that required the estimation of the costs to replace the assets with certifications that would have
the same functionality or utility as the acquired assets. The balance for customer relationships as of January 31, 2022 is
associated primarily with TRC; the corresponding gross amount was determined at the time of the acquisition of TRC by
discounting cash flows expected from existing significant customer relationships. Other than the addition to customer
contracts related to the acquisition of LTI, there were no additions to other purchased intangible assets during Fiscal 2022,
Fiscal 2021 or Fiscal 2020. There were not any impairment losses related to the assets for those years. Amortization
expense related to purchased intangible assets for Fiscal 2022, Fiscal 2021 and Fiscal 2020 were $0.9 million, $0.9 million
and $1.1 million, respectively.
The future amounts of amortization related to purchased intangibles are presented below for the years ending January 31,
2023
2024
2025
2026
2027
Thereafter
Total
NOTE 8 – PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment consisted of the following at January 31, 2022 and 2021:
$
712
392
392
376
300
1,150
$ 3,322
2022
2021
Land and improvements
Building and improvements
Furniture, machinery and equipment
Trucks, trailers and other vehicles
Project development costs (Note 3)
Less - accumulated depreciation
Property, plant and equipment, net
$
863 $
863
5,868
19,132
5,315
7,545
38,723
18,362
$ 10,460 $ 20,361
5,763
18,924
5,895
—
31,445
20,985
As disclosed in Note 3, the Company determined that the carrying value of project development costs incurred by the
Company’s consolidated variable interest entity in preparation for building a new gas-fired power plant became impaired
during Fiscal 2022. Accordingly, an impairment loss related to this asset in the amount of $7.9 million was recorded during
the period.
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Table of Contents
Depreciation for property, plant and equipment was $3.4 million, $3.7 million and $3.5 million for Fiscal 2022, Fiscal
2021 and Fiscal 2020, respectively, which amounts were charged substantially to selling, general and administrative
expenses in each year. The costs of maintenance and repairs were $2.1 million, $1.9 million and $3.4 million for Fiscal
2022, Fiscal 2021 and Fiscal 2020, respectively, which amounts were charged substantially to selling, general and
administrative expenses each year as well.
NOTE 9 – FINANCING ARRANGEMENTS
During April 2021, the Company amended its Amended and Restated Replacement Credit Agreement with the Bank (the
“Credit Agreement”). The amendment extended the expiration date of the Credit Agreement to May 31, 2024 and reduced
the borrowing rate. The Credit Agreement, as amended, includes the following features, among others: a lending
commitment of $50.0 million including a revolving loan with interest at the 30-day LIBOR plus 1.6% (reduced from
2.0%), and an accordion feature which allows for an additional commitment amount of $10.0 million, subject to certain
conditions. The Company may also use the borrowing ability to cover other credit instruments issued by the Bank for the
Company’s use in the ordinary course of business as defined in the Credit Agreement.
At January 31, 2022, the Company did not have any borrowings outstanding under the Credit Agreement. However, the
Bank has issued outstanding letters of credit in the total amount of $21.5 million in support of the activities of APC under
new customer contracts. In connection with the current project development activities of the VIE that is described in Note
3, the Bank issued a letter of credit, outside the scope of the Credit Agreement, in the approximate amount of $3.4 million
as of January 31, 2022 and January 31, 2021, for which the Company has provided cash collateral. As of January 31, 2022,
no amounts have been drawn against this letter of credit.
The Company has pledged the majority of its assets to secure its financing arrangements. The Bank’s consent is not
required for acquisitions, divestitures, cash dividends or significant investments as long as certain conditions are met. The
Bank requires that the Company complies with certain financial covenants at its fiscal year-end and at each of its fiscal
quarter-ends. The Credit Agreement, as amended, includes other terms, covenants and events of default that are customary
for a credit facility of its size and nature, including a requirement to achieve positive adjusted earnings before interest,
taxes, depreciation and amortization, as defined, over each rolling twelve-month measurement period. As of January 31,
2022 and January 31, 2021, the Company was in compliance with the covenants of the Credit Agreement.
The Company expects to amend the Credit Agreement during Fiscal 2023 in order to replace LIBOR with an equivalent
benchmark rate. The Company does not expect that the change will materially impact its consolidated financial statements.
NOTE 10 – COMMITMENTS
Leases
The Company determines if a contract is or contains a lease at inception or upon modification of the contract. A contract
is or contains a lease if it conveys the right to control the use of an identified asset for a period in exchange for
consideration. Control over the use of the identified asset means the lessee has both (a) the right to obtain substantially all
of the economic benefits from the use of the asset and (b) the right to direct the use of the asset. The Company does not
apply this accounting to those leases with terms of twelve (12) months or less and that do not include options to purchase
the underlying assets that the Company is reasonably certain to exercise.
The Company’s operating leases primarily cover office space that expire on various dates through September 2031 and
certain equipment used by the Company in the performance of its construction services contracts. Some of these equipment
leases are embedded in broader agreements with subcontractors or construction equipment suppliers. The Company has
no material finance leases. None of the operating leases includes significant amounts for incentives, rent holidays or price
escalations. Under certain leases, the Company is obligated to pay property taxes, insurance, and maintenance costs.
Operating lease right-of-use assets and associated lease liabilities are recorded in the balance sheet at the lease
commencement date based on the present value of future minimum lease payments to be made over the expected lease
term. As the implicit rate is not determinable in most of the Company’s leases, management uses the Company’s
incremental borrowing rate (currently LIBOR plus 1.6%) at the commencement date in determining the present value of
future payments. The expected lease term includes any option to extend or to terminate the lease when it is reasonably
certain the Company will exercise such option.
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Table of Contents Operating lease expense amounts are recorded on a straight-line basis over the expected lease terms for Fiscal 2022 and
Fiscal 2021 were $3.4 million and $1.8 million, respectively. Operating lease payments for Fiscal 2022 and Fiscal 2021
were $3.3 million and $2.0 million, respectively. For operating leases as of January 31, 2022, the weighted average lease
term is 46 months and the weighted average discount rate is 2.5%.
The Company also uses equipment and occupies other facilities under short-term rental agreements. Rent expense amounts
incurred under operating leases and short-term rental agreements (including portions of the lease expense amounts
disclosed above) and included in costs of revenues were $12.0 million, $7.1 million and $4.0 million for Fiscal 2022,
Fiscal 2021 and Fiscal 2020, respectively. Rent expense incurred under these types of arrangements (including portions of
the lease expense amounts disclosed above) and included in selling, general and administrative expenses were $1.0 million,
$0.9 million and $0.7 million for Fiscal 2022, Fiscal 2021 and Fiscal 2020, respectively.
The aggregate amounts of operating leases added during Fiscal 2022 and Fiscal 2021 were $3.5 million and $3.0 million,
respectively. The following is a schedule of future minimum lease payments for the operating leases that were recognized
in the consolidated balance sheet as of January 31, 2022:
Years Ending January 31,
$
2023
2024
2025
2026
2027
Thereafter
Total lease payments
Less interest portion
Present value of lease payments
Less current portion (included in accrued expenses)
Non-current portion (included in other noncurrent liabilities)
$
1,457
538
379
277
230
1,029
3,910
254
3,656
1,367
2,289
The future minimum lease payments presented above include amounts due under a long-term lease covering the primary
offices and plant for TRC with the founder and current chief executive officer of TRC at an annual rate of $0.3 million
with a term extending through April 30, 2022. The Company expects that the lease will be extended prior to the expiration
of the current term.
Additionally, the future minimum lease payments presented above include amounts due under a new operating lease with
the former president of LTI, covering the office and warehouse space occupied by SMC’s operations located in Hampton,
Virginia, for an initial term extending through December 2026 at an annual lease rate of $0.1 million.
Performance Bonds and Guarantees
In the normal course of business and for certain major projects, the Company may be required to obtain surety or
performance bonding, to cause the issuance of letters of credit, or to provide parent company guarantees (or some
combination thereof) in order to provide performance assurances to clients on behalf of its contractor subsidiaries. As these
subsidiaries are wholly-owned, any actual liability is ordinarily reflected in the financial statement account balances
determined pursuant to the Company’s accounting for contracts with customers. When sufficient information about claims
on guaranteed or bonded projects would be available and monetary damages or other costs or losses would be determined
to be probable, the Company would record such losses. Any amounts that may be required to be paid in excess of the
estimated costs to complete contracts in progress as of January 31, 2022 are not estimable.
As of January 31, 2022, the revenue value of the Company’s unsatisfied bonded performance obligations, covering all of
its subsidiaries, was approximately $235.1 million. In addition, there were bonds outstanding in the aggregate amount of
approximately $1.0 million covering other risks including warranty obligations related to completed activities; these bonds
expire at various dates over the next twelve months. Not all of our projects require bonding.
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As of January 31, 2022, the Company has also provided a financial guarantee, subject to certain terms and conditions, on
behalf of GPS to an original equipment manufacturer in the amount of $3.6 million in support of business development
efforts. During Fiscal 2022, the Company established a liability for the estimated loss related to this guarantee; the
corresponding cost has been included in selling, general and administrative expenses for the year.
Warranties
The Company generally provides assurance-type warranties for work performed under its construction contracts. The
warranties cover defects in equipment, materials, design or workmanship, and most warranty periods typically run from
nine to twenty-four months after the completion of construction on a particular project. Because of the nature of the
Company’s projects, including project owner inspections of the work both during construction and prior to substantial
completion, the Company has not experienced material unexpected warranty costs in the past. Warranty costs are estimated
based on experience with the type of work and any known risks relative to each completed project. The accruals of
liabilities, which are established to cover estimated future warranty costs, are recorded as the contracted work is performed,
and they are included in the amounts of accrued expenses in the consolidated balances sheets. The liability amounts may
be periodically adjusted to reflect changes in the estimated size and number of expected warranty claims.
Employee Benefit Plans
The Company maintains 401(k) savings plans pursuant to which the Company makes discretionary contributions for the
eligible and participating employees. The Company’s expense amounts related to these defined contribution plans were
approximately $2.3 million, $1.9 million and $1.7 million for Fiscal 2022, Fiscal 2021 and Fiscal 2020, respectively. The
Company also maintains nonqualified plans whereunder the payments of certain amounts of incentive compensation
earned by key employees are deferred for periods of four to seven years; payments are conditioned on continuous
employment.
NOTE 11 – LEGAL CONTINGENCIES
In the normal course of business, the Company may have pending claims and legal proceedings. In the opinion of
management, based on information available at this time, there are no current claims and proceedings that could have a
material adverse effect on the consolidated financial statements as of January 31, 2022. During Fiscal 2022, GPS settled
major litigation as described below.
In January 2019, GPS filed a lawsuit against Exelon West Medway II, LLC and Exelon Generation Company, LLC
(together referred to as “Exelon”) in the US District Court for the Southern District of New York for Exelon’s breach of
contract and failure to remedy various conditions which negatively impacted the schedule and the costs associated with
the construction by GPS of a gas-fired power plant for Exelon in Massachusetts. In March 2019, Exelon provided GPS
with a notice intending to terminate the EPC contract under which GPS had been providing services to Exelon. At that
time, the construction project was nearly complete and both of the power generation units included in the plant had
successfully reached first fire. Nevertheless, and among other actions, Exelon provided contractual notice requiring GPS
to vacate the construction site. Exelon asserted that GPS failed to fulfill certain obligations under the contract and was in
default, withholding payments from GPS on invoices rendered to Exelon in accordance with the terms of the contract
between the parties.
In September 2021, Argan’s wholly owned subsidiary, GPS, reached a final settlement of all outstanding claims between
the parties resulting in Exelon making a payment to GPS in the amount of $27.5 million which was in excess of the
previously reported total amount of receivables and contract assets. The excess amount was included in revenues for Fiscal
2022.
NOTE 12 – STOCK-BASED COMPENSATION
On June 23, 2020, the Company’s stockholders approved the adoption of the 2020 Stock Plan (the “2020 Plan”), and the
allocation of 500,000 shares of the Company’s common stock for issuance thereunder. The Company’s board of directors
may make share-based awards under the 2020 Plan to officers, directors and key employees. The 2020 Plan replaces the
2011 Stock Plan (the “2011 Plan”); the Company’s authority to make awards pursuant to the 2011 Plan expired on July
19, 2021. Together, the 2020 Plan and the 2011 Plan are hereinafter referred to as the “Stock Plans.”
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Table of Contents The features of the 2020 Plan are similar to those included in the 2011 Plan. Awards may include nonqualified stock
options, incentive stock options, and restricted or unrestricted stock. The specific provisions for each award made pursuant
to the terms of the 2020 Plan are documented in a written agreement between the Company and the awardee. All stock
options awarded under the 2020 Plan shall have an exercise price per share at least equal to the common stock’s market
value on the date of grant. Stock options shall have terms no longer than ten years. Typically, stock options are awarded
with one-third of each stock option vesting on each of the first three anniversaries of the corresponding award date.
As of January 31, 2022, there were approximately 2,034,401 shares of common stock reserved for issuance under the
Stock Plans; this number includes 407,250 shares of common stock available for future awards under the 2020 Plan.
Stock Options
A summary of stock option activity under the Company’s approved Stock Plans for Fiscal 2022, Fiscal 2021 and Fiscal
2020, along with corresponding weighted average per share amounts, are presented below (shares in thousands):
Outstanding, February 1, 2019
Granted
Exercised
Forfeited
Outstanding, January 31, 2020
Granted
Exercised
Forfeited
Outstanding, January 31, 2021
Granted
Exercised
Forfeited
Outstanding, January 31, 2022
Exercisable, January 31, 2021
Exercisable, January 31, 2022
Shares
Exercise
Price
Remaining
Term (years) Fair Value
7.54 $ 11.22
1,140 $
238 $
(61) $
(46) $
1,271 $
242 $
(68) $
(40) $
1,405 $
67 $
(42) $
(25) $
1,405 $
44.01
44.76
26.67
48.47
44.83
37.26
24.17
57.44
44.17
45.47
34.01
54.28
44.35
7.18 $ 11.06
6.90 $ 10.39
6.17 $ 10.31
938 $
1,110 $
46.09
45.19
5.95 $ 11.58
5.56 $ 10.98
The changes in the number of non-vested options to purchase shares of common stock for Fiscal 2022, Fiscal 2021 and
Fiscal 2020, and the weighted average fair value per share for each number, are presented below (shares in thousands):
Non-vested, February 1, 2019
Granted
Vested
Forfeitures
Non-vested, January 31, 2020
Granted
Vested
Forfeitures
Non-vested, January 31, 2021
Granted
Vested
Forfeitures
Non-vested, January 31, 2022
Shares Fair Value
375 $ 10.05
238 $
9.60
(134) $ 10.25
(31) $ 10.28
9.74
448 $
6.53
242 $
9.98
(207) $
8.52
(16) $
8.01
467 $
8.54
67 $
8.46
(231) $
7.05
(8) $
7.80
295 $
The total intrinsic value amounts of the stock options exercised during Fiscal 2022, Fiscal 2021 and Fiscal 2020 were $0.6
million, $1.5 million and $1.4 million, respectively. At January 31, 2022, the aggregate market value amounts of the shares
of common stock subject to outstanding and exercisable stock options that were “in-the-money” exceeded the aggregate
exercise prices of such options by $2.2 million and $1.8 million, respectively.
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Restricted Stock Units
The changes in the maximum number of restricted stock units for Fiscal 2022, Fiscal 2021 and Fiscal 2020 and the
weighted average fair value per share for each number, are presented below (shares in thousands):
Outstanding, February 1, 2019
Awarded
Outstanding, January 31, 2020
Awarded
Outstanding, January 31, 2021
Awarded
Issued
Outstanding, January 31, 2022
Shares Fair Value
36 $ 16.63
36 $ 22.25
72 $ 19.44
45 $ 14.95
117 $ 17.71
145 $ 39.52
(40) $ 20.64
222 $ 31.48
Performance-Based Restricted Stock Units
Pursuant to the terms of the Stock Plan and as described in the corresponding agreements with the executives, the Company
awarded performance-based restricted stock units to four senior executives in April 2021 and two senior executives in
2020 and 2019 covering up to 49,000, 45,000 and 36,000 maximum total numbers of shares of common stock, respectively,
plus a number of shares to be determined based on the amount of cash dividends deemed paid on shares earned pursuant
to the awards. The issuance of the number of shares earned under the agreements, free of related restrictions, depends on
the total return performance of the Company’s common stock measured against the performance of a peer-group of
common stocks over three-year periods.
During Fiscal 2022, the three-year vesting period for the restricted stock units awarded in April 2018 concluded and it was
determined that 40,471 shares of common stock, including shares attributable to cash dividends, were earned pursuant to
the performance criteria and other terms of the 2011 Plan and the applicable award agreements. These shares were issued
to the awardees in April 2021.
Renewable Performance-Based Restricted Stock Units
In April 2021, the Company awarded renewable energy project performance-based restricted stock units to two senior
executives at GPS as described in the corresponding agreements with the executives. Each award covers 5,000 shares of
the Company’s common stock plus a number of shares to be determined based on the amount of cash dividends deemed
paid on shares earned pursuant to the awards. The issuance of the shares, free of restrictions, shall be based on the success
of GPS in increasing the amount of RUPO related to renewable energy projects, as defined, during certain periods within
the three-year term of each award. The awards establish RUPO hurdle amounts for separate periods of time defined in the
awards, and assign a certain portion of the award shares to each hurdle. If a RUPO hurdle is exceeded (each is mutually
exclusive), the number of shares earned based on the achievement of the applicable hurdle will be issued to the executives
at the end of the corresponding period. If a RUPO hurdle amount is not achieved within the period of time defined in the
awards, the award shares assigned to the hurdle are forfeited.
Time-Based Restricted Stock Units
During Fiscal 2022, the Company also awarded time-based restricted stock units covering a total of 82,250 shares of
common stock to members of the Company’s board of directors, senior executives and other employees pursuant to the
terms of the Stock Plans and as described in the corresponding agreements with each awardee. Time-based restricted stock
units covering 51,750 shares will vest in equal installments on each of the first three anniversaries of the award date.
Accordingly, at each vesting date, one-third of the award shares plus a number of shares to be determined based on the
amount of cash dividends deemed paid on shares earned pursuant to the awards will be issued to each awardee. The rest
of the restricted stock units covering 30,500 shares will vest on the three-year anniversaries of award.
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Fair Value
The fair value amounts of stock options and restricted stock units are recorded as stock compensation expense over the
terms of the corresponding awards. Expense amounts related to stock awards were $3.5 million, $2.9 million and $2.1
million for Fiscal 2022, Fiscal 2021 and Fiscal 2020, respectively.
At January 31, 2022, there was $6.0 million in unrecognized compensation cost related to outstanding stock awards that
the Company expects to expense over the next three years.
The Company estimates the weighted average fair value of stock options on the date of award using a Black-Scholes option
pricing model. The Company believes that its past stock option exercise activity is sufficient to provide it with a reasonable
basis upon which to estimate the expected life of newly awarded stock options. Risk-free interest rates are determined by
blending the rates for three-to-five-year U.S. Treasury notes. The dividend yield is based on the Company’s current annual
regular dividend amount. The calculations of the expected volatility factors are based on the monthly closing prices of the
Company’s common stock for the five-year periods preceding the dates of the corresponding awards.
The fair value amounts for the performance-based restricted stock units have been determined by using the per share
market price of the Company’s common stock on the dates of award and the target number of shares for the awards (50%
of the maximum number), by assigning equal probabilities to the thirteen possible payout outcomes at the end of each
three-year term, and by computing the weighted average of the outcome amounts. For each award, the estimated fair value
amount was calculated to be 88.5% of the aggregate market value of the target number of shares on the award date. For
the renewable performance-based restricted stock units, which were awarded for the first time in April 2021, the fair value
of each award was determined to be 50% of the aggregate market value of the shares of common stock covered by the
award on the date of the award. For the time-based restricted stock units, the fair value of each award equals the aggregate
market price for the number of shares covered by each award on the date of award.
NOTE 13 – INCOME TAXES
Reconciliations of Income Tax (Expense) Benefit
The components of the amounts of income tax (expense) benefit for Fiscal 2022, Fiscal 2021 and Fiscal 2020 are presented
below:
Current:
Federal
State
Deferred:
Federal
State
Income tax (expense) benefit
2022
2021
2020
$ (10,921) $ 6,654 $
(643)
(11,564)
(83)
6,571
77
336
413
341
(133)
208
6,825
(185)
6,640
$ (11,356) $ (1,074) $ 7,053
(7,720)
75
(7,645)
The amounts of interest and penalties related to income taxes that were incurred by the Company during Fiscal 2022,
Fiscal 2021 and Fiscal 2020 were not material. Foreign income tax expense amounts for Fiscal 2022, Fiscal 2021 and
Fiscal 2020 were not material.
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The Company’s income tax amounts differed from corresponding amounts computed by applying the federal corporate
income tax rate of 21% to the income (loss) before income taxes for Fiscal 2022, Fiscal 2021 and Fiscal 2020 as presented
below:
Computed expected income tax (expense) benefit
Difference resulting from:
2022
2021
$ (9,883) $ (5,226) $ 10,030
2020
State income taxes, net of federal tax effect
Excess executive compensation
Bad debt loss
Foreign tax rate differential
Net operating loss carryback benefit (see discussion below)
Elimination of net operating loss benefits
Goodwill impairment losses
Other permanent differences and adjustments, net
(614)
(1,296)
(425)
352
—
—
—
510
81
(420)
6,205
(722)
—
(7,239)
(763)
(119)
$ (11,356) $ (1,074) $ 7,053
(7)
(420)
160
173
4,392
—
—
(146)
Income tax (expense) benefit
A valuation allowance in the amount of $7.1 million was established against the deferred tax asset amount created by the
net operating loss of APC’s subsidiary in the U.K. for Fiscal 2020. However, this effect was substantially offset by an
income tax benefit for Fiscal 2020 in the amount of approximately $6.2 million that was the estimated favorable federal
income tax impact of bad debt loss on certain loans made to APC from Argan, which were determined to be uncollectible
during Fiscal 2020. A portion of the bad debt loss was reversed for Fiscal 2022 which resulted in charge to federal income
tax expense for the period in the amount of $0.4 million.
Net Operating Loss (“NOL”) Carryback
In an effort to combat the adverse economic impacts of the COVID-19 crisis, the US Congress passed the Coronavirus,
Aid, Relief, and Economic Security Act (the “CARES Act”) that was signed into law on March 27, 2020. This wide-
ranging legislation was an emergency economic stimulus package that included spending and tax breaks aimed at
strengthening the U.S. economy and funding a nationwide effort to curtail the effects of the outbreak of COVID-19.
The tax changes of the CARES Act included a temporary suspension of the limitations on the future utilization of certain
NOLs and re-established a carryback period for certain losses to five years. The NOLs eligible for carryback under the
CARES Act include the Company’s domestic NOL for Fiscal 2020, which was approximately $39.5 million. The Company
made the appropriate filing with the IRS requesting carryback refunds of income taxes paid for the years ended January
31, 2017, 2016 and 2015.
A deferred tax asset in the amount of $8.3 million was recorded as of January 31, 2020 associated with the income tax
benefit of the NOL for Fiscal 2020. With the enactment of the CARES Act, the asset was moved to income taxes receivable
(included in other current assets in the consolidated financial statements as of January 31, 2022 and 2021) where the value
was increased to approximately $12.7 million. The carryback provided a favorable rate benefit for the Company as the
loss, which was incurred in a year where the statutory federal tax rate was 21%, has been carried back to tax years where
the tax rate was higher. The net amount of this additional income tax benefit, approximately $4.4 million, was recorded in
Fiscal 2021.
Research and Development Tax Credits
During Fiscal 2019, the Company completed a detailed review of the activities of its engineering staff on major EPC
services projects in order to identify and quantify the amounts of research and development tax credits that may have been
available to reduce prior year income taxes. This study focused on project costs incurred during the three-year period
ended January 31, 2018.
Based on the results of the study, management identified and estimated significant amounts of income tax benefits that
were not previously recognized in the Company’s operating results for any prior year reporting period. The amount of
research and development tax credit benefit recognized in Fiscal 2019 was $16.6 million. During Fiscal 2020, deferred tax
assets related to the research and development tax credits were reduced by $0.4 million. As described below, the Internal
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Revenue Service (the “IRS”) has issued its revenue agents reports relating to the examinations of the Company’s
consolidated federal income tax returns for Fiscal 2016, Fiscal 2017 and Fiscal 2018; the tax returns for the earlier two
years were amended to include research and development tax credits.
The amount of identified but unrecognized income tax benefits related to research and development tax credits as of
January 31, 2022 and 2021 is $5.0 million, for which the Company has established a liability for uncertain income tax
return positions, most of which is included in accrued expenses as of January 31, 2022 and 2021. The final outcome of
these uncertain tax positions is not yet determinable. However, the Company does not expect that the amount of
unrecognized tax benefits will significantly change due to any expiration of statutes of limitation over the next 12 months.
However, it is possible that the disputes with the IRS related to the Company’s federal research and development tax
credits (see discussion of income tax returns below) could be resolved within the next twelve months depending on the
results of the scheduled appeals hearing with the IRS. If resolution of the disputes occurs, it would result in the Company’s
elimination of at least a substantial portion of the amount of the liability for uncertain income tax positions discussed
above. As of January 31, 2022, the Company does not believe that it has any other material uncertain income tax positions
reflected in its accounts.
As of January 31, 2022 and 2021, the balances of other current assets in the consolidated balance sheet included total
income tax refunds receivable and prepaid income taxes in the amounts of approximately $29.5 million and $26.9 million,
respectively. The income tax refunds include the amounts expected to be received from the IRS upon completion of the
tax return examination appeals process identified below and the amount expected to be received from the IRS upon its
processing of the Company’s NOL carryback refund request discussed above.
Deferred Taxes
The tax effects of temporary differences that are reflected in deferred taxes as of January 31, 2022 and 2021 included the
following:
Assets:
Net operating loss carryforwards
Stock awards
Lease liabilities
Research and development credit carryforwards
Purchased intangibles
Accrued expenses and other
2022
2021
$ 14,360 $ 14,192
2,549
775
102
234
1,422
19,274
2,325
772
269
19
1,828
19,573
Liabilities:
Purchased intangibles
Property and equipment
Construction contracts
Right-of-use assets
Other
Valuation allowances
Deferred taxes, net
(3,533)
(1,334)
(1,034)
(768)
(43)
(6,712)
(12,404)
(3,513)
(1,801)
(968)
(770)
(176)
(7,228)
(11,797)
249
$
457 $
The Company acquired unused NOLs for federal income tax reporting purposes from TRC that are subject to limitations
imposed by Section 382 of the Internal Revenue Code of 1986, as amended. These losses are subject to annual limits that
reduce the aggregate amount of NOLs available to the Company in the future to approximately $5.9 million. These NOLs
are available to offset future taxable income and, if not utilized, begin expiring during 2032. The Company also has certain
NOLs that will be available to the Company for state income tax reporting purposes that are substantially similar to the
federal NOLs.
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The Company’s ability to realize deferred tax assets, including those related to the NOLs discussed above, depends
primarily upon the generation of sufficient future taxable income to allow for the Company’s use of temporarily deferred
deductions and tax planning strategies. If such estimates and assumptions change in the future, the Company may be
required to record additional valuation allowances against some or all of its deferred tax assets resulting in additional
income tax expense in the future. At this time, based substantially on the strong earnings performance of the Company’s
power industry services reporting segment, management believes that it is more likely than not that the Company will
realize the benefit of significantly all of its deferred tax assets.
Income Tax Returns
The Company is subject to federal and state income taxes in the U.S., and income taxes in Ireland and the U.K. Tax
treatments within each jurisdiction are subject to the interpretation of the related tax laws and regulations which require
significant judgment to apply. The Company is no longer subject to income tax examinations by authorities for its fiscal
years ended on or before January 31, 2018 except for several notable exceptions including Ireland, the U.K. and several
states where the open periods are one year longer.
The IRS conducted examinations of the Company’s amended federal consolidated income tax returns for Fiscal 2016 and
Fiscal 2017, and the Company’s federal income tax return for Fiscal 2018 and has issued its final revenue agents reports
that document its understanding of the facts, attempts to summarize the Company’s arguments in support of the research
and development claims and states its position which disagrees with the Company’s treatment of a substantial amount of
the costs that support the Company’s claims for Fiscal 2016, Fiscal 2017 and Fiscal 2018. The Company believes that its
arguments are sound and that the reports do not present any new facts relating to the issues or make any new arguments
that would cause it to make any adjustments to its accounting for the research and development claims as of January 31,
2022. The Company has submitted formal protests of the findings of the IRS examiner and is pursuing its income tax
positions with the IRS through the established protest and appeals process. The Company has also formally protested the
conclusions reached by two states, where the Company filed tax returns reflecting the benefits of certain research and
development credits, that the credits are not allowable. The Company expects that the ultimate settlement of the income
tax disputes will be resolved on bases favorable to the Company.
Solar Energy Projects
During Fiscal 2022 and Fiscal 2021, the Company invested approximately $5.0 million and $1.3 million, respectively, in
limited liability companies that make equity investments in solar energy projects that are eligible to receive energy tax
credits. The passive investments have been accounted for under the equity method and the net balances have been reported
within other assets in our consolidated balance sheets. Each tax credit, when recognized, is recorded as a reduction of the
corresponding investment balance with an offsetting reduction in the balance of accrued taxes payable in accordance with
the deferral method, each representing a non-cash transaction. Investment tax credits in the approximate amounts of $4.5
million and $1.1 million were recognized during Fiscal 2022 and Fiscal 2021, respectively. As of January 31, 2022, the
Company’s had no remaining cash investment commitments related to these projects.
During Fiscal 2022 and Fiscal 2021, the corresponding investment balances were adjusted to reflect the Company’s share
of the losses of the investment entities, which have been included as other expense in the Company’s consolidated
statements of earnings. The Company has also established deferred taxes related to the differences in the book and tax
bases of the investments. These investments are expected to provide positive overall returns over their six-year expected
lives.
Supplemental Cash Flow Information
The amounts of cash paid for income taxes during Fiscal 2022, Fiscal 2021 and Fiscal 2020 were $14.0 million, $5.5
million and $3.1 million, respectively. During Fiscal 2022, Fiscal 2021 and Fiscal 2020, the Company received cash
refunds of previously paid income taxes from various taxing authorities in the total amounts of $0.2 million, $1.0 million
and $8.4 million, respectively.
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Table of Contents NOTE 14 – NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO THE STOCKHOLDERS OF ARGAN
Basic and diluted net income (loss) per share amounts for Fiscal 2022, Fiscal 2021 and Fiscal 2020 are computed as follows
(shares in thousands except in notes (1) and (2) below the chart):
2022
2021
2020
Net income (loss) attributable to the stockholders of Argan
$ 38,244 $ 23,851 $ (42,689)
Weighted average number of shares outstanding – basic
Effect of stock awards (1)(2)
Weighted average number of shares outstanding – diluted
15,715
198
15,913
15,668
157
15,825
15,621
—
15,621
Net income (loss) per share attributable to the stockholders of Argan
Basic
Diluted
$
$
2.43 $
2.40 $
1.52 $
1.51 $
(2.73)
(2.73)
(1) The weighted average numbers of shares determined on a dilutive basis for Fiscal 2022 and Fiscal 2021 exclude the
effects of antidilutive stock options covering 570,167 and 638,001 shares of common stock, respectively, as the
options had exercise prices per share in excess of the average market price per share for the applicable year.
(2) For Fiscal 2020, the weighted average number of shares determined on a dilutive basis excludes any effect of
outstanding stock awards which covered 1,303,000 shares of the Company's common stock as of January 31, 2020 as
the Company incurred a net loss for the year.
NOTE 15 – CASH DIVIDENDS AND COMMON STOCK REPURCHASES
During Fiscal 2022, Fiscal 2021 and Fiscal 2020, the Company made regular quarterly cash dividend payments of $0.25
per share of common stock. The Company also made special cash dividend payments in the amount of $1.00 per share of
common stock in July 2020 and December 2020.
Pursuant to authorizations provided by the Company’s board of directors, the Company began to repurchase shares of its
common stock in November 2021 (the “Repurchase Plan”). By January 31, 2022, the Company had repurchased 527,752
shares of common stock, all on the open market, for an aggregate price of approximately $20.4 million, or $38.60 per
share.
NOTE 16 – CUSTOMER CONCENTRATIONS
The majority of the Company’s consolidated revenues relate to performance by the power industry services segment which
provided 78%, 81% and 57% of consolidated revenues for Fiscal 2022, Fiscal 2021 and Fiscal 2020, respectively. For
Fiscal 2022, Fiscal 2021 and Fiscal 2020, the Company’s industrial services segment represented 19%, 17% and 40% of
consolidated revenues, respectively.
For Fiscal 2022, the Company’s most significant customer relationships included one power industry service customer
which accounted for 57% of consolidated revenues. For Fiscal 2021, the Company’s most significant customer
relationships included one power industry service customer which accounted for 67% of consolidated revenues. For Fiscal
2020, the Company’s most significant customer relationships included two power industry service customers which
accounted for 22% and 15% of consolidated revenues, respectively.
The accounts receivable balances from three major customers represented 22%, 15% and 12% of the corresponding
consolidated balance as of January 31, 2022 and accounts receivable balances from three major customers represented
26%, 11% and 11% of the corresponding consolidated balance as of January 31, 2021. The contract asset balances related
to two major customers represented 31% and 13% of the corresponding consolidated balance as of January 31, 2022.
Contract asset balances related to two major customers represented 64% and 12% of the corresponding consolidated
balance as of January 31, 2021
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NOTE 17 – SEGMENT REPORTING
Segments represent components of an enterprise for which discrete financial information is available that is evaluated
regularly by the Company’s chief executive officer, who is the chief operating decision maker, in determining how to
allocate resources and in assessing performance. The Company’s reportable segments recognize revenues and incur
expenses, are organized in separate business units with different management teams, customers, talents and services, and
may include more than one operating segment.
Intersegment revenues and the related cost of revenues, are netted against the corresponding amounts of the segment
receiving the intersegment services. For Fiscal 2022, 2021 and 2020, intersegment revenues totaled approximately $2.8
million, $4.3 million and $3.3 million, respectively. Intersegment revenues for the aforementioned periods primarily
related to services provided by the industrial fabrication and field services segment to the power industry services segment
and were based on prices negotiated by the parties.
Summarized below are certain operating results and financial position data of the Company’s reportable business segments
for Fiscal 2022, Fiscal 2021 and Fiscal 2020. The “Other” column in each summary includes the Company’s corporate
expenses.
Year Ended
January 31, 2022
Revenues
Cost of revenues
Gross profit
Selling, general and administrative expenses
Impairment loss
Income (loss) from operations
Other income, net
Income (loss) before income taxes
Income tax expense
Net income
Industrial
Services
Telecom
Services
Power
Services
$ 398,089 $ 97,890 $ 13,391 $
81,391
16,499
8,167
—
8,332
—
317,130
80,959
28,323
7,901
44,735
2,545
11,117
2,274
2,146
—
128
—
128 $
$ 47,280 $ 8,332 $
Other
Totals
— $ 509,370
409,638
—
99,732
—
47,321
8,685
7,901
—
44,510
(8,685)
2,552
7
47,062
(8,678)
(11,356)
$ 35,706
Amortization of intangibles
Depreciation
Property, plant and equipment additions
$
208 $
605
713
662 $
— $
2,325
107
433
597
— $
4
5
870
3,367
1,422
Current assets
Current liabilities
Goodwill
Total assets
$ 322,448 $ 25,681 $ 2,957 $ 156,198 $ 507,284
223,027
28,033
553,585
209,829
18,476
345,956
1,748
—
156,886
9,534
9,467
44,002
1,916
90
6,741
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Year Ended
January 31, 2021
Revenues
Cost of revenues
Gross profit
Selling, general and administrative expenses
Income (loss) from operations
Other income, net
Income (loss) before income taxes
Income tax expense
Net income
Industrial
Services
Telecom
Services
Power
Services
$ 319,353 $ 65,263 $ 7,590 $
57,257
8,006
7,358
648
—
266,993
52,360
21,795
30,565
1,777
5,889
1,701
1,987
(286)
—
(286) $
$ 32,342 $
648 $
Other
Totals
— $ 392,206
330,139
—
62,067
—
39,041
7,901
23,026
(7,901)
1,859
82
24,885
(7,819)
(1,074)
$ 23,811
Amortization of intangibles
Depreciation
Property, plant and equipment additions
$
242 $
704
1,043
662 $
— $
2,592
338
414
316
— $
5
—
904
3,715
1,697
Current assets
Current liabilities
Goodwill
Total assets
$ 360,552 $ 22,014 $ 1,959 $ 161,695 $ 546,220
276,087
27,943
602,630
985
—
162,212
261,030
18,476
394,014
13,119
9,467
42,998
953
—
3,406
Year Ended
January 31, 2020
Power
Services
Industrial
Services
Telecom
Services
Other
Totals
Revenues
Cost of revenues
Gross (loss) profit
Selling, general and administrative expenses
Impairment losses
Loss from operations
Other income, net
Loss before income taxes
Income tax benefit
Net loss
$ 135,729 $ 94,682 $ 8,586 $
85,859
8,823
7,810
2,823
(1,810)
—
152,854
(17,125)
26,835
2,072
(46,032)
7,535
7,104
1,482
2,135
—
(653)
—
$ (38,497) $ (1,810) $
— $ 238,997
245,817
—
(6,820)
—
44,125
7,345
4,895
—
(55,840)
(7,345)
8,075
540
(47,765)
(653) $ (6,805)
7,053
$ (40,712)
Amortization of intangibles
Depreciation
Property, plant and equipment additions
$
291 $
694
5,069
664 $
2,418
1,638
181 $
396
340
— $
5
11
1,136
3,513
7,058
Current assets
Current liabilities
Goodwill
Total assets
NOTE 18 – SUBSEQUENT EVENTS
$ 320,257 $ 21,766 $
135,518
18,476
352,034
6,441
9,467
46,321
2,938 $ 76,794 $ 421,755
144,034
1,279
796
27,943
—
—
487,540
84,636
4,549
Subsequent to January 31, 2022, the Company continued to repurchase shares of its common stock pursuant to the
Repurchase Plan. As of April 8, 2022, the date of the last subsequent transaction, the Company had repurchased 442,079
shares since year-end, all on the open market, for an aggregate price of approximately $17.1 million, or $38.69 per share.
On April 8, 2022, the Company’s board of directors declared a regular cash dividend in the amount of $0.25 per share,
payable on April 29, 2022 to stockholders of record on April 21, 2022. On April 13, 2022, the Company filed a Current
Report on Form 8-K announcing an additional authorized increase in its share Repurchase Plan, from $50 million to $75
million.
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�����, ���.
��� ������ ������, ����� ���
���������, �������� �����
ABOUT US
SENIOR MANAGEMENT
Rainer H. Bosselmann
Chairman of the Board of Directors,
Chief Execu�ve Officer
David H. Watson
Senior Vice President, Chief Financial Officer,
Treasurer and Secretary
Richard H. Deily
Vice President, Corporate Controller
DIRECTORS
Rainer H. Bosselmann
Cynthia A. Flanders
Peter W. Getsinger
William F. Griffin
John R. Jeffrey
Mano S. Koilpillai
William F. Leimkuhler
W.G. Champion Mitchell
James W. Quinn
AUDITORS
Grant Thornton LLP
Arlington, Virginia
COUNSEL
Culhane Meadows PLLC
New York, New York
TRANSFER AGENT
Con�nental Stock Transfer & Trust Company
New York, New York
ANNUAL MEETING
The 2022 Annual Mee�ng of Argan, Inc. will be
held on June 21, 2022 at 11:00 a.m. at One Church
Street, Room 104, Rockville, Maryland 20850.
STOCKHOLDER INFORMATION
Our common stock is listed on the NYSE under the
symbol AGX.
Copies of the Annual Report on Form 10-K as filed
with the Securi�es and Exchange Commission are
available without charge to Stockholders of record
as of April 27, 2022 upon request at Corporate
Headquarters.
SUBSIDIARIES
Gemma Power Systems
www.gemmapower.com
The Roberts Company
www.robertscompany.com
Atlan�c Projects Company
www.atlan�cprojects.com
SMC Infrastructure Solu�ons
www.smcis.com
Transfer Agent
project in the United States.
Front Cover: Guernsey Power Sta�on is an 1,875 MW natural gas-fired power plant that Gemma Power Systems is construc�ng in Guernsey
County, Ohio. Using state-of the art combined cycle technology and an air-cooling system for each power train, Guernsey Power Sta�on has
the capability to provide electricity to approximately one million homes. It is the largest, single-phase, gas-fired power plant construc�on
Back Cover: A ground view of one of three air-cooled condensers at Guernsey Power Sta�on that u�lizes dry cooling technology to reduce
water usage by as much as 95% compared to a standard water-cooled power plant.
Inside Back Cover: Atlan�c Projects Company completed the mechanical installa�on of one of the world’s largest biomass boilers for the
Teesside (UK) Renewable Energy Plant in early 2021. TeesREP is a 299 MW power plant that will burn primarily wood pellets to generate
electricity for 600,000 homes.
ANNUAL
REPORT