The following discussion summarizes the financial position of Argan, Inc. and
its subsidiaries as of April 30, 2020, and the results of their operations for
the three months ended April 30, 2020 and 2019, and should be read in
conjunction with (i) the unaudited condensed consolidated financial statements
and notes thereto included elsewhere in this Quarterly Report on Form 10-Q and
(ii) the consolidated financial statements and accompanying notes included in
our Annual Report on Form 10-K for the fiscal year ended January 31, 2020 that
was filed with the SEC on April 14, 2020 (the "Annual Report").
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 Quarterly Report on Form 10-Q that may constitute
"forward-looking statements." The words "believe," "expect," "anticipate,"
"plan," "intend," "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. 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 this
Quarterly Report on Form 10-Q and our 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 markets, 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 US 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 US.
We may make additional acquisitions of and/or investments in companies with
potential for profitable growth that reflect more than one industrial focus. We
expect that they will be held in separate subsidiaries that will be operated in
a manner that best provides value for our stockholders.
Overview
We have disclosed in prior filings that APC has encountered significant
operational and contractual challenges in completing the TeesREP construction
project, which is a biomass-fired power plant under construction in Teesside,
England.
By April 30, 2019, APC's estimates of the unfavorable financial impacts on
forecasted costs of the numerous and unique difficulties on this particular
project, including weather delays, inefficiencies due to unanticipated scope and
design changes from preliminary plans, project task re-sequencing and various
work interruptions, had escalated substantially from the estimates prepared for
the prior year-end. As a result, for the three-month period ended April 30,
2019, we reversed profit in the amount of $0.7 million that had been recorded in
prior periods and recorded a loss related to this project in the amount of $27.6
million.
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Based on analyses that have been continually updated over the last twelve
months, management currently expects that the forecasted costs for the TeesREP
project at completion will exceed projected revenues by approximately $36.2
million. The total amount of the expected loss on this project has been
reflected in the condensed consolidated financial statements as of April 30,
2020, including $2.7 million in loss that was recorded during the three-month
period ended April 30, 2020.
During the fourth quarter of Fiscal 2020, APC and its customer, the engineering,
procurement and construction services contractor on the TeesREP project, agreed
to operational and commercial terms for the completion of the project. At the
time, this framework addressed the project schedule, payment terms, the scope of
the remaining effort, performance guarantees and other terms and conditions for
APC to reach substantial completion of its portion of the total project.
Although this negotiation returned a meaningful amount of stability to the
continuation of the project efforts, the framework did not resolve significant
past commercial differences which may have to be addressed through applicable
dispute resolution mechanisms. Currently, it is not possible to predict
precisely how, when and on what terms (if any) the past commercial differences
will be resolved.
Construction on the TeesREP project was suspended on March 24, 2020 due to the
COVID-19 pandemic. At the time of the work suspension, APC had completed
approximately 90% of its subcontracted work. The amount of the remaining
contract loss reserve as of April 30, 2020 was approximately $4.1 million; the
comparable balance at January 31, 2020 was $5.8 million. These balances were
included in accrued expenses in the accompanying corresponding condensed
consolidated balance sheets. The combined amounts of accounts receivable and
contract assets related to the TeesREP project and included in the condensed
consolidated balance sheets were $15.5 million as of April 30, 2020 and $19.2
million as of January 31, 2020. In addition, Argan has caused certain letters of
credit to be issued to APC's customer by our Bank and has provided a parent
company performance guarantee related to the TeesREP project on behalf of APC
(see Notes 6 and 7 to the accompanying condensed consolidated financial
statements).
The future identification of additional adverse impacts on APC's efforts to
complete the TeesREP project, including any new problems that may arise related
to the resumption of construction work before the COVID-19 outbreak is
controlled and under the existing contractual structure, may result in
additional losses that will be reflected in operating results when identified
and quantified.
During August 2019, GPS received a full notice to proceed ("FNTP") with
activities under an EPC services contract to build a 1,875 MW combined cycle
natural gas-fired power plant in Guernsey County, Ohio. The Guernsey Power
Station was jointly developed by Caithness Energy, L.L.C. and Apex Power Group,
LLC. The gradual ramp-up of activity on this project favorably impacted the
condensed consolidated financial statements for the three months ended April 30,
2020 resulting in increased revenues for the power industry services segment as
well as improved consolidated cash flow. Substantial completion of this project
is currently scheduled to occur by the end of 2022.
Due substantially to the increasing revenues of GPS, consolidated revenues for
the three months ended April 30, 2020 were $60.1 million, which represented an
increase of $10.6 million, or 21.4%, from consolidated revenues of $49.5 million
reported for the three months ended April 30, 2019. The revenues of the power
industry services segment, including GPS, represented 80.8% and 40.8% of
consolidated revenues for the three months ended April 30, 2020 and 2019,
respectively. The revenues of TRC and SMC for the three months ended April 30,
2020 declined by 64.0% and 21.1%, respectively, from the comparable amounts
reported for the three months ended April 30, 2019, and together represented
19.2% of consolidated revenues for the quarter ended April 30, 2020.
As reported by the business segments, the revenue results for the three months
ended April 30, 2020 were mixed. However, we believe that all of our businesses
were adversely impacted, to some degree, by difficulties presented by the
COVID-19 outbreak. The results for APC were hurt by the postponement of Irish
works projects and the suspension of construction activities on the TeesREP
project. The challenges of managing the continuing activities of the Guernsey
Power Station project during this period of various health and safety
restrictions resulted in project spending by GPS falling slightly short of prior
expectations. In addition, our consolidated revenues suffered from the effects
of project delays by customers of both TRC and SMC attributable to the
restrictive work environments caused by the pandemic.
Consolidated gross profit for the three months ended April 30, 2020 was $4.0
million, or 6.7% of the corresponding consolidated revenues, which reflected the
favorable impact of higher revenues offset partially by the adverse impact of
the additional contract loss recorded for the period. Our gross loss reported
for the three months ended April 30, 2019 in the amount of $21.0 million was due
to the loss recorded for the TeesREP project in the amount of $27.6 million,
which was partially offset by the favorable gross profits reported by GPS, TRC
and SMC for the period. For the three months ended April 30, 2020 and 2019,
selling, general and administrative expenses were $10.3 million and $9.6
million, respectively.
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We considered the unanticipated and sizable contract loss identified for the
TeesREP project to be an event which triggered our assessment of the goodwill
associated with APC and the recording of an impairment loss of $2.1 million for
the three months ended April 30, 2019. The net amount of our other income, which
includes primarily investment income earned on our cash equivalents and
short-term investments, declined by $1.2 million to $1.1 million for the three
months ended April 30, 2020.
As more fully described below, the income tax benefit recorded for the three
months ended April 30, 2020 included primarily the benefit, in the estimated
amount of $4.2 million, of the carryback of our consolidated NOL for the year
ended January 31, 2020 to the tax year ended January 31, 2015. On the other
hand, consistent with our treatment of the NOL of APC's subsidiary in the UK
last year, we did not record any income tax benefit related to the NOL of the UK
subsidiary for the three months ended April 30, 2020.
Primarily due to the factors discussed above, the consolidated net loss
attributable to our stockholders was $0.8 million, or $0.05 per diluted share,
for the three months ended April 30, 2020. For the three months ended April 30,
2019, we reported a consolidated net loss attributable to our stockholders of
$29.8 million, or $1.91 per diluted share.
Major Customer Contracts
On March 10, 2020, we announced that in late February 2020 GPS entered into an
EPC services contract with ESC Brooke County Power I, LLC to construct the
Brooke County Power plant, a 920 MW natural gas-fired power generation facility,
in Brooke County, West Virginia. The facility is being developed by Energy
Solutions Consortium, LLC and construction activities are currently scheduled to
start in 2020 once financial close is achieved. On March 12, 2020, we announced
that GPS had entered into an EPC services contract with NTE Connecticut, LLC to
construct Killingly Energy Center, a 650 MW natural gas-fired power plant, in
Killingly, Connecticut. The facility is being developed by NTE Energy, LLC
("NTE"). Construction activities are currently scheduled to start in 2020 once
financial close is achieved. We anticipate adding the value of each of these new
contracts to project backlog at times closer to their expected start dates.
At this time, for all of the contract awards with pending start dates including
the two new contracts identified above, we cannot predict with certainty when
the projects will commence. The start date for construction is generally
controlled by the project owners.
We announced in March 2018 that GPS entered into an EPC services contract with
an affiliate of NTE to construct an approximately 500 MW natural gas-fired power
plant in Rockingham County, North Carolina. The Reidsville Energy Center will be
similar to two gas-fired power plants substantially completed by GPS for NTE
during Fiscal 2019, the Kings Mountain Energy Center located in Kings Mountain,
North Carolina, and the Middletown Energy Center located in Middletown, Ohio.
Due to project owner delays, including a grid connection dispute between the
project owner and a public utility, contract activities have not yet started for
this new project. If the current dispute with the public utility is not resolved
on terms that move the project forward, we will most likely remove the value of
the Reidsville Energy Center from project backlog.
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. Even though we are providing financial
and technical support to the project development effort through a consolidated
VIE and project development milestones continue to be achieved, we have not
included the value of this contract in our project backlog. Due to several
factors that are slowing the pace of the development of this project, including
additional time being required to secure the natural gas supply for the plant
and to obtain the necessary equity financing, we currently cannot predict when
construction will commence, if at all.
The aggregate rated electrical output amount for the natural gas-fired power
plants for which we have signed EPC services contracts is approximately 7.3
gigawatts with an aggregate contract value in excess of $3.0 billion. We include
the value of an EPC services contract in project backlog when we believe that it
is probable that the project will commence within a reasonable timeframe, among
other factors. Our project backlog amount was approximately $1.3 billion at both
April 30 and January 31, 2020. 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 2 to
the accompanying condensed consolidated financial statements). Cancellations or
reductions may occur that may reduce project backlog and our expected future
revenues.
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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 US.
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
has been challenged by uncertainty in the capital markets. The viability of
future power revenue forecasts by power plant owners and operators, particularly
independent power producers, depends, to a significant degree, on the amount of
future capacity supply secured for a particular power source located within the
electricity region coordinated by PJM Interconnection LLC ("PJM"). 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 natural gas-fired
power plants located within the geographic footprint of the electric power
system operated by PJM, the regional transmission organization that coordinates
the movement of wholesale electricity in all or parts of 13 states and the
District of Columbia.
In December 2019, Federal regulators voted to effectively raise the bids of
subsidized resources selling their power into the PJM wholesale capacity market.
Clean energy advocates and other market observers feared the move by the
regulators would severely hinder incentives intended to bring new zero emissions
resources online, while favoring incumbent fossil fuels. PJM was provided 90
days to comply with the order and to provide regulators with a timeline for its
next capacity auction. PJM had previously suspended all activities and deadlines
relating to the base capacity auctions for the 2022/2023 and 2023/2024
electricity delivery years. PJM has submitted its compliance filing response to
FERC for review and approval, including a proposed plan for restarting the
capacity auctions. Uncertainty relating to PJM capacity auctions may continue to
disrupt capital markets. As a result, our commencement of the new EPC power
plant projects could be delayed until PJM releases new capacity auction bidding
rules approved by the FERC regulators and announces future capacity auction
schedules.
Besides the downturn in the demand for electric power during the COVID-19
outbreak in the US that is discussed below, other unfavorable factors include an
increase in the amount of power generating capacity provided by renewable energy
assets, improvements and decreasing prices in renewable energy storage solutions
and increased environmental activism. Protests against fossil-fuel related
energy projects continue to garner media attention and stir public skepticism
about new pipelines resulting in project delays due to onsite protest
demonstrations, indecision by local officials and lawsuits. Pipeline approval
delays may jeopardize projects that are needed to bring supplies of natural gas
to planned gas-fired power plant sites, thereby increasing the risk of power
plant project delays or cancellations.
In the New England and mid-Atlantic regions of the US, 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 which
continue to be deferred by project owners.
Market Outlook
Although the total amount of electricity generated by utility-scale power
facilities in calendar year 2019 declined by 1.3% from the total amount in 2018,
the 2019 amount was the second highest total annual amount of electricity
generated by utility-scale power plants since 2010. In the reference case
included in its Annual Energy Outlook 2020 released in January 2020, the US
Energy Information Administration (the "EIA") again forecasted slow but steady
growth in net electricity generation through 2050 with average annual increases
of slightly less than 1.0% per year. The growth rate is tempered by new
electricity-efficient devices and production processes replacing older,
less-efficient appliances, heating, cooling and ventilation systems and capital
equipment.
Despite the overall decline in the amount of electricity generated in the US in
2019 and the increases in the amounts of electricity provided by utility-scale
wind and solar power sources, the amount of electricity generated by natural
gas-fired power plants rose by 7.7% during 2019, and it represented 38.4% of the
total electric power generated in the US in 2019. The combined amount of power
generated by the wind and the sun represented 10.8% of total utility-scale power
generation in 2019. For 2018, the corresponding power shares were 35.2% and
9.9%, respectively. The amount of electricity generated from coal decreased by
15.7% in 2019 from its generation amount for 2018, and coal's share of the
total, utility-scale electricity generation mix declined from 27.4% for 2018 to
23.5% for 2019. During 2019, power companies retired or converted roughly 15,100
MW of coal-fired electricity generation, reported to be enough to power about 15
million homes. That retirement capacity reduction was second only to the record
19,300 MW of capacity shut down in 2015.
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In summary, the share of the electrical power generation mix in the US fueled by
natural gas, the sun and wind continued to rise during 2019, while the share
fueled by coal continued its fall. Over the ten-year period ended in 2019, the
amount of electrical power fueled by natural gas in the US increased by 72%
while the amount of utility-scale power generated by coal fell by 45%. This
dramatic shift is a primary cause of the significant reductions in the annual
power plant emissions of carbon dioxide, sulfur dioxide and nitrogen oxides over
this same ten-year period.
However, reduced economic activity in the US related to the COVID-19 pandemic
has caused significant changes in energy supply and demand patterns. Crude oil
prices, in particular, have fallen significantly since the beginning of 2020,
largely driven by reduced oil demand because of COVID-19 mitigation efforts.
Despite more recent stability, crude oil prices have remained at some of their
lowest levels in more than 20 years causing some uncertainty related to the
future supplies and prices for natural gas.
In its Short-Term Energy Outlook released in May 2020, EIA now forecasts that
total electric power sector generation in the US will decline by 5% in 2020.
Most of the expected decline is reflected in lower fossil fuel generation,
especially at coal-fired power plants. EIA expects that coal-fired power plant
generation will fall by 25% in 2020. The updated forecast for natural gas
generation is that it will be relatively flat this year, reflecting currently
favorable fuel costs and the addition of new generating capacity. Renewable
energy sources are forecasted to account for the largest portion of new
generating capacity in 2020, driving EIA's forecast of 11% growth in renewable
generation by the electric power sector. The ultimate adverse impacts of the
COVID-19 outbreak in the US on the forecast of electricity generation over the
long-term are not known at this time.
In the reference case of the 2020 outlook identified above, the EIA predicted
that coal-fired and nuclear power generating capacity would decline by
approximately 47% and 20% by 2050, respectively, representing only 13% and 12%
shares of the electricity generation mix by 2050, respectively. It is important
to note that most of the reduction in the coal-fired and nuclear capacity was
already predicted to occur in the period 2020-2025. As a result, natural
gas-fired power generating capacity was forecasted to increase by 26% over the
next five years and by 67% by 2050 (before any adjustments for adverse and
long-lasting effects of the COVID-19 pandemic on the demand for electricity). It
is logical that this outlook represented the driver for the realization by at
least certain power producers that the near-term addition of new natural
gas-fired power plants to the utility-scale power generation fleet in the US is
necessary. As a result, we have experienced meaningful growth in the number of
new EPC service contracts awarded to us.
In our view, the competitive landscape in the EPC services market for natural
gas-fired power plant construction has changed significantly. Several
significant competitors have announced that they were exiting the market for a
variety of reasons. Others have announced intentions to avoid entering into
fixed-price contracts. While the competitive market remains dynamic, we expect
that there will be fewer competitors for new gas-fired power plant EPC project
opportunities in the foreseeable future.
We believe that the future long-term prospects for natural gas-fired power plant
construction remain generally favorable as natural gas is the primary source for
power generation in our country. 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 at consistently low prices. The
abundant availability of cheap, less carbon-intense and higher efficiency
natural gas should continue to be a significant factor in the economic
assessment of future power generation capacity additions. However, as identified
above, stability in the availability of natural gas supplies and natural gas
prices, particularly in the short-term, may be threatened due to pandemic-caused
uncertainties.
Despite the pandemic, we believe that the development of natural gas-fired power
generation facilities in the US should continue to provide new construction
opportunities for us although, in the near term, the pace of new opportunities
emerging may be restrained and the starts of awarded EPC projects may be
delayed. We are committed to the rational pursuit of new construction projects
and the future growth of our revenues. This may result in our decision 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 EPC services contract to us. We believe that the
Company has a reputation as an accomplished and cost-effective provider of EPC
and other large project construction contracting services. We are convinced that
the recent series of new EPC projects awarded to us confirms the soundness of
our belief. 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 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.
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Impacts of the COVID-19 Pandemic on Our Business Operations
The world-wide COVID-19 pandemic began to impact our businesses noticeably in
March 2020, most significantly overseas.
During the three month-period ended April 30, 2020, almost all planned power
plant outage and maintenance projects in Ireland were postponed for an
indefinite period other than emergency tasks, which necessitated the temporary
furlough of a significant number of APC's skilled and semi-skilled workers.
Construction on the TeesREP project was suspended on March 24, 2020 due to the
COVID-19 pandemic, pending preparations being made by the contractors and
subcontractors to comply with new and evolving government guidance concerning
public health protocols. Only a small number of critical maintenance staff
remains on site. APC has obtained emergency governmental payroll subsidies and
other government support that is available in Ireland and the UK for the benefit
of furloughed and terminated employees.
At the time of the suspension of work on the TeesREP project, APC had completed
approximately 90% of its subcontracted work. Nonetheless, the project shutdowns
had a meaningful impact on the revenues of APC for the quarter ended April 30,
2020 which declined by about 25% from the revenues reported for the prior
consecutive quarter. The dates on which the operations of APC will resume
unrestricted operations and the ultimate impacts of the health crisis on the
future revenues and financial performance of APC are not known.
In the state of Ohio, the location of the Guernsey Power Station, our most
significant active project, the construction and building trades were among the
professions allowed to continue working by its governor. To the extent possible
under the circumstances, current work on the project, which includes primarily
site preparation efforts, design engineering and early phases of construction,
has continued. The revenues earned during the quarter ended April 30, 2020 based
on the activity on this project represented a significant portion of our
consolidated revenues for the quarter. However, as the project ramps-up into
heavier construction phases later this year, COVID-19 impacts could become more
meaningful. GPS is monitoring supply-chain issues for impacts on equipment
delivery delays related to the COVID-19 health crisis and the recent executive
order placing restrictions on the foreign supplied components installed in our
nation's electric grid in the name of national security.
The ultimate impacts of the health crisis and/or the executive order on the
Guernsey project and on the future revenues and financial performance of GPS are
not known. The force majeure clauses of our fixed-price construction contracts,
including the EPC contract for Guernsey Power Station, do provide relief that
will help to mitigate certain of these adverse effects.
Even before the onset of the outbreak and related restrictions, the revenues of
TRC and SMC for the first quarter of the fiscal year ending January 31, 2021
were expected to be less than revenues of the comparable period of the prior
year. However, the revenues of both of these businesses for the three months
ended April 30, 2020 were negatively impacted by project delays attributable to
the restrictive COVID-19 business environment. Future revenues of these
businesses for Fiscal 2021 may also be adversely impacted by COVID-19 effects.
The decline in interest rates during the pandemic period has reduced our cash
investment returns meaningfully. However, as described below, the emergency
legislation that has been enacted by the US government in response to the
COVID-19 health crisis, allows us to carryback the NOL incurred by us last year,
as determined for federal income tax reporting purposes, to our income tax
reporting year ended January 31, 2015. The favorable effect of the carryback was
recorded and is included in the income tax benefit reported by us for the
quarter ended April 30, 2020.
The administrative and operational support staffs at the subsidiaries and
corporate headquarters have been maintained at pre-pandemic levels in general.
Substantial amounts of required duties and responsibilities, including the
timely filing of financial reports, have been fulfilled by staff members working
remotely due to pandemic restrictions imposed by local and state authorities.
Despite the migration from processes that have typically relied on the creation
and maintenance of hard-copy evidence in order to document the operation of
internal controls, we believe that our system of internal control over financial
reporting has not been fundamentally altered and that the effectiveness of the
design and operation of internal controls remained materially consistent during
the three month-period ended April 30, 2020.
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Comparison of the Results of Operations for the Three Months Ended April 30,
2020 and 2019
We reported a net loss attributable to our stockholders of $0.8 million, or
$0.05 per diluted share, for the three months ended April 30, 2020. For the
three months ended April 30, 2019, we reported a comparable net loss amount of
$29.8 million, or $1.91 per diluted share.
The following schedule compares our operating results for the three months ended
April 30, 2020 and 2019 (dollars in thousands):
Three Months Ended April 30,
2020 2019 $ Change % Change
REVENUES
Power industry services $ 48,612 $ 20,203 $ 28,409 140.6 %
Industrial fabrication and field
services 9,744 27,069 (17,325 ) (64.0 )
Telecommunications infrastructure
services 1,792 2,272 (480 ) (21.1 )
Revenues 60,148 49,544 10,604 21.4
COST OF REVENUES
Power industry services 45,710 44,526 1,184 2.7
Industrial fabrication and field
services 8,982 24,271 (15,289 ) (63.0 )
Telecommunications infrastructure
services 1,447 1,773 (326 ) (18.4 )
Cost of revenues 56,139 70,750 (14,611 ) (20.7 )
GROSS PROFIT (LOSS) 4,009 (21,026 ) 25,035 N/M
Selling, general and administrative
expenses 10,344 9,588 756 7.9
Impairment loss - 2,072 (2,072 ) (100.0 )
LOSS FROM OPERATIONS (6,335 ) (32,686 ) 26,351 80.6
Other income, net 1,088 2,252 (1,164 ) (51.7 )
LOSS BEFORE INCOME TAXES (5,247 ) (30,434 ) 25,187 82.8
Income tax benefit 4,454 521 3,933 755.9
NET LOSS (793 ) (29,913 ) 29,120 97.3
Net loss attributable to
non-controlling interests (30 ) (113 ) 83 73.5
NET LOSS ATTRIBUTABLE TO
THE STOCKHOLDERS OF ARGAN, INC. $ (763 ) $ (29,800 ) $ 29,037 97.4
N/M - Not meaningful.
Revenues
Power Industry Services
The revenues of the power industry services business increased by 140.6%, or
$28.4 million, to $48.6 million for the three months ended April 30, 2020
compared with revenues of $20.2 million for the three months ended April 30,
2019, primarily due to the increasing revenues associated with the construction
of the Guernsey Power Station. The revenues of this business represented
approximately 80.8% of consolidated revenues for the quarter ended April 30,
2020 and approximately 40.8% of consolidated revenues for the prior year
quarter. GPS reached substantial completion on four gas-fired power plant
projects late in Fiscal 2019 and concluded activities on a fifth gas-fired power
plant during the quarter ended April 30, 2019. As a result, the revenues of GPS
declined substantially for the quarter ended April 30, 2019. The revenues of
this segment for the three-month period ended April 30, 2019 also were
negatively impacted by unfavorable adjustments related to the TeesREP project.
As previously discussed above, a detailed review of this project by management
for the quarter ended April 30, 2019 revealed the significant loss on this
project which was recognized in the results of operations for the quarter.
Industrial Fabrication and Field Services
The revenues of industrial fabrication and field services (representing the
business of TRC) provided 16.2% of consolidated revenues for the three months
ended April 30, 2020, which reflected a reduction in revenues of $17.3 million,
or 64.0%, to $9.7 million compared to revenues of $27.1 million for the three
months ended April 30, 2019. With the completion of several large projects last
year, TRC has been focused on rebuilding its business. Recent new project awards
have increased TRC's project backlog to approximately $38.3 million as of April
30, 2020 from $14.0 million at the beginning of the quarter.
- 25 -
The largest portion of the revenues of TRC continues to be provided by
industrial field services. The major customers of TRC include some of North
America's largest forest products companies, large fertilizer producers as well
as other chemical and energy companies with plants located in the southeast
region of the US.
Telecommunications Infrastructure Services
The revenues of this business segment (representing the business of SMC) were
$1.8 million for the three months ended April 30, 2020 compared with revenues of
$2.3 million for the three months ended April 30, 2019.
Cost of Revenues
Despite the increase in consolidated revenues for the three months ended April
30, 2020 compared with last year's first quarter, the consolidated cost of
revenues declined between the quarters. These costs were $56.1 million and $70.8
million for the three months ended April 30, 2020 and 2019, respectively, a
reduction of approximately 20.7%. Last year, our cost of revenues included the
loss recorded by APC for the quarter ended April 30, 2019 in the amount of $27.6
million which had a significant unfavorable effect on our gross profit, causing
us to report a consolidated gross loss for the quarter in the amount of $21.0
million.
For the three months ended April 30, 2020, we reported a consolidated gross
profit of approximately $4.0 million which represented a gross profit percentage
of approximately 6.7% of corresponding consolidated revenues. The gross profit
percentage for the three months ended April 30, 2020 was adversely affected by
the continuation of challenges confronting the management of the TeesREP
project, now including the suspension of construction activities due to the
COVID-19 outbreak, which resulted in our recording additional loss for this
project in the amount of $2.7 million.
Selling, General and Administrative Expenses
These costs were $10.3 million and $9.6 million for the three months ended April
30, 2020 and 2019, respectively, representing 17.2% and 19.4% of consolidated
revenues for the corresponding periods, respectively. The amount for the three
months ended April 30, 2020 included the costs of maintaining core members of
the operations staff at GPS whose time is typically charged to active projects
to a greater degree, and the costs of maintaining intact the key staff
organizations at corporate headquarters, GPS, TRC and SMC. We expect these
costs, expressed as a percentage of corresponding revenues, to trend downward
through the remaining quarters of Fiscal 2021 and next year, primarily driven by
the expected increase in consolidated revenues over the same periods.
Impairment Loss
We did not consider the unfavorable results of TRC for the quarter ended April
30, 2020 to be a goodwill impairment assessment triggering event as a low level
of revenues was expected while the significant growth in its project backlog
since January 31, 2020, due to several recent and large project awards, was
unexpected. APC recorded a substantial loss on TeesREP during the three months
ended April 30, 2019. We considered the recognition of a contract loss of this
magnitude to be an event triggering a re-assessment of the goodwill which
resulted in our conclusion that the remaining balance was impaired. Accordingly,
an impairment loss was recorded in April 2019 in the amount of $2.1 million.
Other Income
For the three months ended April 30, 2020 and 2019, the net amounts of other
income were $1.1 million and $2.3 million, respectively, which represented a
reduction of 51.7% between the comparable quarterly periods. The amounts
reported for this line item reflect primarily investment income earned on funds
maintained in a money market account and interest income earned on CDs. Although
the aggregate amount of invested funds has increased between the quarters and
since January 31, 2020, the significant drop in interest rates that has occurred
during the COVID-19 pandemic has had a meaningful adverse effect on the returns
earned on our invested funds.
Income Tax Benefits
We recorded a total income tax benefit for the three months ended April 30, 2020
in the amount of approximately $4.5 million, which reflected primarily the net
operating loss carryback benefit discussed in the following paragraph.
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In a response to the COVID-19 health crisis, the US Congress passed the CARES
Act that was signed into law on March 27, 2020. This wide-ranging legislation is
an emergency economic stimulus package that includes spending and tax breaks
aimed at strengthening the US economy and funding a nationwide effort to curtail
the effects of the outbreak of COVID-19. The CARES Act has provided many
opportunities for taxpayers to evaluate their 2018 and 2019 income tax returns
to identify potential tax refunds. One such area is the utilization of NOLs. The
tax changes of the CARES Act remove the limitations on the future utilization of
certain NOLs and re-establish a carryback period for certain losses to five
years. The losses eligible for carryback under the CARES Act include our
consolidated NOL for Fiscal 2020, which was approximately $38.5 million.
Substantially all of this loss now may be carried back for application against
our taxable income for the year ended January 31, 2015. This provides a
favorable rate benefit for us as the loss, which was incurred in a year where
the statutory federal tax rate was 21%, will be carried back to a tax year where
the tax rate was a higher. The amount of this rate benefit, approximately $4.2
million, was recorded in the three-month period ended April 30, 2020.
We estimate that our annual effective income tax rate for Fiscal 2021 before
discrete items will approximate 27.8%. This tax rate differs from the statutory
federal tax rate of 21% due primarily to the unfavorable effects of permanent
differences relating to nondeductible travel and entertainment expenses, certain
nondeductible executive compensation and interest income earned on our notes
receivable from the VIE.
We recorded an income tax benefit for the three months ended April 30, 2019 in
the amount of approximately $0.5 million which primarily reflected the tax
benefit of the loss incurred by our domestic operations. We did not record any
income tax benefit related to the net loss reported by APC's UK operations for
the period.
Liquidity and Capital Resources as of April 30, 2020
At April 30 and January 31, 2020, our balances of cash and cash equivalents were
$262.9 million and $167.4 million, respectively. During this same period, our
working capital increased by $4.9 million to $282.6 million as of April 30, 2020
from $277.7 million as of January 31, 2020.
The net amount of cash provided by operating activities for the three months
ended April 30, 2020 was $40.2 million. The sources of cash for the period
included a temporary increase in the balance of contract liabilities, primarily
associated with the early phases of the Guernsey Power Station construction, and
a reduction in the balances of accounts receivable, primarily at the TRC and APC
operations, in the amounts of $37.1 million and $15.0 million, respectively. In
addition, our net loss for the quarter ended April 30, 2020 was more than offset
by the favorable adjustments related to non-cash income and expense items, which
represented a net source of cash in the total amount of $9.6 million. As
suggested above, our income tax accounting for the quarter ended April 30, 2020
included an entry to record the carryback of our net operating loss incurred for
the year ended January 31, 2020 to our tax year ended January 31, 2015. The loss
carryback should result in a refund of federal income taxes in the amount of
$12.3 million. This tax refund receivable has been included in the balance of
other current assets as of April 30, 2020, which was the primary cause of the
increase in this balance of $13.6 million during the quarter, a use of cash. The
Company used cash in operations during the three months ended April 30, 2020 in
the amount of $8.2 million to reduce the level of accounts payable and accrued
expenses.
A primary source of cash for the three months ended April 30, 2020 was the net
maturities of short-term investments, certificates of deposit issued by the
Bank, in the amount of $60.0 million. Non-operating activities used cash during
the three months ended April 30, 2020, including the payment of a quarterly cash
dividend in the total amount of $3.9 million and capital expenditures in the
amount of $0.7 million. As of April 30, 2020, there were no restrictions with
respect to inter-company payments from GPS, TRC, APC or SMC to the holding
company. However, during the prior year, certain loans made by Argan to APC were
determined to be uncollectible.
Last year, the net amount of cash used by operating activities for the three
months ended April 30, 2019 was $36.4 million. Our net loss for the period,
offset partially by the favorable adjustments related to non-cash income and
expense items, used cash in the total amount of $26.2 million. Due substantially
to the increased activity at TRC, accounts receivable increased during the three
months ended April 30, 2019, representing a use of cash in the amount of $12.0
million. The Company also used cash during the three months ended April 30, 2019
in the amount of $10.5 million to reduce the level of accounts payable and
accrued liabilities.
However, the net balance of contract assets and liabilities declined by $8.4
million during the quarter due primarily to a reduction in the amount of costs
incurred and estimated earnings recognized on certain active projects in excess
of the amounts billed on those projects, which represented a source of cash. Due
primarily to the receipt of expected income tax refunds, the balance of other
assets decreased by $4.0 million during the three months ended April 30, 2019, a
source of cash.
- 27 -
A primary source of cash required to fund operations during the three months
ended April 30, 2019 was the net maturity of short-term investments in the
amount of $9.0 million. Cash proceeds in the amount of $1.6 million were
received from the exercise of stock options during the quarter. Non-operating
activities used cash during the three months ended April 30, 2019, including
primarily the payment of a quarterly cash dividend in the total amount of $3.9
million. Our operating subsidiaries also used cash during the three-month period
ended April 30, 2019 in the amount of $2.0 million to fund capital expenditures.
At April 30, 2020, most of our balance of cash and cash equivalents was invested
in a money market fund with most of its total assets invested in cash, US
Treasury obligations and repurchase agreements secured by US Treasury
obligations. Most of our domestic operating bank accounts are maintained with
the Bank. We do maintain certain Euro-based bank accounts in Ireland and certain
pound sterling-based bank accounts in the UK in support of the operations of
APC.
Our Credit Agreement, which expires on May 31, 2021, 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 2.0%, and an accordion
feature which allows for an additional commitment amount of $10.0 million,
subject to certain conditions. We may 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 April 30, 2020, we had $9.3 million of
outstanding letters of credit issued under the Credit Agreement. However, we had
no outstanding borrowings. Additionally, in connection with the current project
development activities by a 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 the Company has provided cash collateral.
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 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. At April 30 and January 31, 2020, we were compliant with the
financial covenants of the Credit Agreement.
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 contractor subsidiaries.
For example, we maintain a variety of commitments that are generally made
available to provide support for various commercial provisions in our
construction contracts. For certain projects, we are required by project owners
to provide guarantees related to our services or work. 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 may be
responsible for monetary damages or other legal remedies. Certain project owners
may request that we obtain surety bonds for their benefit in connection with EPC
services contract performance obligations. As is typically required by any
surety bond, the Company 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 April 30, 2020, the revenue value of the
Company's unsatisfied bonded performance obligations was less than the value of
RUPO disclosed in Note 2 to the accompanying condensed consolidated financial
statements. In addition, as of April 30, 2020, there were bonds outstanding in
the aggregate amount of approximately $152 million covering other risks
including warranty obligations related to projects completed by GPS; these bonds
expire at various dates during the years ending January 31, 2021 and 2022.
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 guaranteed 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 April 30, 2020 are not estimable.
On behalf of APC, Argan provided a parent company performance guarantee to its
customer, the EPC services contractor on the TeesREP project, and caused the
Bank to issue letters of credit as security (see Notes 6 and 7 to the
accompanying condensed consolidated financial statements). As disclosed above,
these letters of credit represent a little over 70% of the amount of outstanding
credit under the Credit Agreement as of April 30, 2020.
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 which resulted in the award of an EPC services contract to
GPS.
- 28 -
We believe that cash on hand, 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 line of credit, will be adequate to meet our
general business needs in the foreseeable future. For the quarter ended April
30, 2020, to assure an optimum level of liquidity during this period of
uncertainty and to mitigate the market risks represented by the COVID-19
pandemic, management decided to temporarily maintain larger balances of cash and
cash equivalents relative to short-term investments.
In general, we maintain significant liquid capital on our balance sheet to help
ensure our ability to maintain bonding capacity and to provide parent company
performance guarantees for EPC and other construction projects. Any future
acquisitions, or other significant 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.
Earnings before Interest, Taxes, Depreciation and Amortization ("EBITDA")
The following table presents the determinations of EBITDA for the three months
ended April 30, 2020 and 2019, respectively (amounts in thousands):
Three Months Ended
April 30,
2020 2019
Net loss, as reported $ (793 ) $ (29,913 )
Income tax benefit (4,454 ) (521 )
Depreciation 937 829
Amortization of purchased intangible assets 225 299
EBITDA (4,085 ) (29,306 )
EBITDA of non-controlling interests (30 ) (115 )
EBITDA attributable to the stockholders of Argan, Inc. $ (4,055 ) $ (29,191 )
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 US
GAAP, the following table reconciles the amounts of EBITDA for the applicable
periods, as presented above, to the corresponding amounts of net cash flows
provided by or used in operating activities that are presented in our condensed
consolidated statements of cash flows for the three months ended April 30, 2020
and 2019 (amounts in thousands).
Three Months Ended
April 30,
2020 2019
EBITDA $ (4,085 ) $ (29,306 )
Current income tax benefit 12,668 780
Stock option compensation expense 642 413
Impairment loss - 2,072
Other non-cash items 328 25
Decrease (increase) in accounts receivable 14,980 (12,049 )
(Increase) decrease in other assets (13,600 ) 3,808
Decrease in accounts payable and accrued expenses (8,230 ) (10,497 )
Change in contracts in progress, net 37,484 8,372
Net cash provided by (used in) operating activities $ 40,187 $ (36,382 )
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
US 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 condensed 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.
- 29 -
Critical Accounting Policies
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 consider the accounting policies related to revenue recognition on long-term
construction contracts; income tax reporting; the accounting for business
combinations; the subsequent valuation of goodwill, other indefinite-lived
assets and long-lived assets; the valuation of employee stock options; 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 joint ventures and variable interest entities. An expanded discussion
of our critical accounting policies is included in Item 7 of Part II of our
Annual Report. During the three-month period ended April 30, 2020, there have
been no material changes in the way we apply the critical accounting policies
described therein.
Recently Issued Accounting Pronouncements
In December 2019, the FASB issued ASU 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, are not expected to alter our accounting for income
taxes.
In 2016, the FASB also issued ASU 2016-13, Measurement of Credit Losses on
Financial Instruments. The requirements of this new standard cover, among other
provisions, the methods that businesses shall use to estimate amounts of credit
losses. As subsequently amended, the adoption of this new guidance, which became
effective for us on February 1, 2020, did not affect our consolidated financial
statements.
There are no other recently issued accounting pronouncements that have not yet
been adopted that we consider material to our consolidated financial statements.
As required for us, we adopted ASU 2016-02, Leases, as of February 1, 2019.
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