Argan 10Q 2023 Q2 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)


☑	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period Ended

July 31, 2022


☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT

For the Transition Period from to

Commission File Number 001-31756

(Exact Name of Registrant as Specified in Its Charter)


Delaware		13-1947195
(State or Other Jurisdiction of Incorporation)		(I.R.S. Employer Identification No.)

One Church Street, Suite 201, Rockville, Maryland 20850

(Address of Principal Executive Offices) (Zip Code)

(301) 315-0027

(Registrant’s Telephone Number, Including Area Code)

(Former Name, Former Address and Former Fiscal Year, if Changed since Last Report)

Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 (the “Exchange Act”) during the preceding 12 months (or for such shorter period that the Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No ☐

Indicate by check mark whether the Registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the Registrant was required to submit such files). Yes þ No ☐

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 company. See the definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer ☐ Accelerated filer þ Non-accelerated filer ☐ Smaller reporting company ☐ Emerging growth company ☐

If an emerging growth company, indicate by check mark if the Registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the Registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑


Title of Each Class	Trading Symbol(s)	Name of Each Exchange on Which Registered
Common Stock, $.15 par value	AGX	New York Stock Exchange

Indicate the number of shares outstanding of each of the Registrant’s classes of common stock, as of the latest practicable date.

Common stock, $0.15 par value: 13,884,195 shares as of September 6, 2022.

ARGAN, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EARNINGS

(In thousands, except per share data)

(Unaudited)


	Three Months Ended				Six Months Ended
	July 31,				July 31,
	2022		2021		2022		2021
REVENUES	$	118,110	$	133,008	$	218,387	$	259,349
Cost of revenues		93,723		105,356		174,262		207,983
GROSS PROFIT		24,387		27,652		44,125		51,366
Selling, general and administrative expenses		10,984		10,331		21,559		20,223
INCOME FROM OPERATIONS		13,403		17,321		22,566		31,143
Other income (expense), net		505		(260)		1,100		452
INCOME BEFORE INCOME TAXES		13,908		17,061		23,666		31,595
Income tax expense		(9,686)		(4,191)		(11,959)		(7,959)
NET INCOME		4,222		12,870		11,707		23,636
Foreign currency translation adjustments		(687)		(139)		(1,951)		(257)
COMPREHENSIVE INCOME	$	3,535	$	12,731	$	9,756	$	23,379

NET INCOME PER SHARE
Basic	$	0.30	$	0.82	$	0.81	$	1.50
Diluted	$	0.30	$	0.81	$	0.80	$	1.48

WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING
Basic		14,134		15,769		14,516		15,748
Diluted		14,247		15,982		14,616		15,978

CASH DIVIDENDS PER SHARE	$	0.25	$	0.25	$	0.50	$	0.50

The accompanying notes are an integral part of these condensed consolidated financial statements.

ARGAN, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Dollars in thousands, except per share data)


	July 31,		January 31,
	2022		2022
	(Unaudited)		(Note 1)
ASSETS
CURRENT ASSETS
Cash and cash equivalents	$	143,344	$	350,472
Short-term investments		175,643		90,026
Accounts receivable, net		24,888		26,978
Contract assets		8,678		4,904
Other current assets		25,640		34,904
TOTAL CURRENT ASSETS		378,193		507,284
Property, plant and equipment, net		9,507		10,460
Goodwill		28,033		28,033
Other purchased intangible assets, net		2,941		3,322
Right-of-use, deferred tax and other assets		4,396		4,486
TOTAL ASSETS	$	423,070	$	553,585

LIABILITIES AND EQUITY
CURRENT LIABILITIES
Accounts payable	$	38,180	$	41,822
Accrued expenses		39,816		53,315
Contract liabilities		64,016		127,890
TOTAL CURRENT LIABILITIES		142,012		223,027
Noncurrent liabilities		4,022		4,963
TOTAL LIABILITIES		146,034		227,990

COMMITMENTS AND CONTINGENCIES

STOCKHOLDERS’ EQUITY
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; 15,827,772 and 15,788,673 shares issued at July 31, 2022 and January 31, 2022, respectively; 13,884,195 and 15,257,688 shares outstanding at July 31, 2022 and January 31, 2022, respectively		2,374		2,368
Additional paid-in capital		160,229		158,190
Retained earnings		193,205		188,690
Less treasury stock, at cost – 1,943,577 and 530,985 shares at July 31, 2022 and January 31, 2022, respectively		(73,573)		(20,405)
Accumulated other comprehensive loss		(4,402)		(2,451)
TOTAL STOCKHOLDERS’ EQUITY		277,833		326,392
Non-controlling interest		(797)		(797)
TOTAL EQUITY		277,036		325,595
TOTAL LIABILITIES AND EQUITY	$	423,070	$	553,585

The accompanying notes are an integral part of these condensed consolidated financial statements.

ARGAN, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

FOR THE THREE AND SIX MONTHS ENDED JULY 31, 2022 AND 2021

(Dollars in thousands)

(Unaudited)


	Common Stock			Additional						Accumulated
	Outstanding	Par		Paid-in		Retained		Treasury		Other Comprehensive		Non-controlling		Total
	Shares	Value		Capital		Earnings		Stock		Loss		Interest		Equity
Balances, May 1, 2022	14,585,908	$	2,374	$	159,170	$	192,463	$	(47,482)	$	(3,715)	$	(797)	$	302,013
Net income	—		—		—		4,222		—		—		—		4,222
Foreign currency translation loss	—		—		—		—		—		(687)		—		(687)
Stock compensation expense	—		—		1,059		—		—		—		—		1,059
Common stock repurchases	(701,713)		—		—		—		(26,091)		—		—		(26,091)
Cash dividends	—		—		—		(3,480)		—		—		—		(3,480)
Balances, July 31, 2022	13,884,195	$	2,374	$	160,229	$	193,205	$	(73,573)	$	(4,402)	$	(797)	$	277,036

Balances, May 1, 2021	15,769,440	$	2,366	$	155,007	$	172,934	$	(33)	$	(1,199)	$	1,741	$	330,816
Net income	—		—		—		12,870		—		—		—		12,870
Foreign currency translation loss	—		—		—		—		—		(139)		—		(139)
Stock compensation expense	—		—		930		—		—		—		—		930
Cash dividends	—		—		—		(3,942)		—		—		—		(3,942)
Balances, July 31, 2021	15,769,440	$	2,366	$	155,937	$	181,862	$	(33)	$	(1,338)	$	1,741	$	340,535

Balances, February 1, 2022	15,257,688	$	2,368	$	158,190	$	188,690	$	(20,405)	$	(2,451)	$	(797)	$	325,595
Net income	—		—		—		11,707				—		—		11,707
Foreign currency translation loss	—		—		—		—		—		(1,951)		—		(1,951)
Stock compensation expense	—		—		1,979		—		—		—		—		1,979
Stock option exercises and other share-based award settlements	39,099		6		60		—		—		—		—		66
Common stock repurchases	(1,412,592)		—		—		—		(53,168)		—		—		(53,168)
Cash dividends	—		—		—		(7,192)		—		—		—		(7,192)
Balances, July 31, 2022	13,884,195	$	2,374	$	160,229	$	193,205	$	(73,573)	$	(4,402)	$	(797)	$	277,036

Balances, February 1, 2021	15,702,969	$	2,356	$	153,315	$	166,110	$	(33)	$	(1,081)	$	1,741	$	322,408
Net income	—		—		—		23,636		—		—		—		23,636
Foreign currency translation loss	—		—		—		—		—		(257)		—		(257)
Stock compensation expense	—		—		1,609		—		—		—		—		1,609
Stock option exercises and other share-based award settlements	66,471		10		1,013		—		—		—		—		1,023
Cash dividends	—		—		—		(7,884)		—		—		—		(7,884)
Balances, July 31, 2021	15,769,440	$	2,366	$	155,937	$	181,862	$	(33)	$	(1,338)	$	1,741	$	340,535

The accompanying notes are an integral part of these condensed consolidated financial statements.

ARGAN, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)


	Six Months Ended July 31,
	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	11,707	$	23,636
Adjustments to reconcile net income to net cash (used in) provided by operating activities
Stock compensation expense		1,979		1,609
Depreciation		1,556		1,741
Lease expense		1,319		1,938
Equity in (income) loss of solar energy investments		(1,070)		325
Deferred income tax expense		373		1,001
Amortization of purchased intangible assets		399		453
Other		(609)		(96)
Changes in operating assets and liabilities
Accounts receivable		2,090		(14,407)
Contract assets		(3,774)		1,258
Other assets		9,252		(3,161)
Accounts payable and accrued expenses		(16,124)		(8,793)
Contract liabilities		(63,874)		41,680
Net cash (used in) provided by operating activities		(56,776)		47,184

CASH FLOWS FROM INVESTING ACTIVITIES
Purchases of short-term investments		(175,000)		—
Maturities of short-term investments		90,000		50,000
Purchases of property, plant and equipment		(638)		(1,011)
Investments in solar energy projects		—		(4,085)
Net cash (used in) provided by investing activities		(85,638)		44,904

CASH FLOWS FROM FINANCING ACTIVITIES
Common stock repurchases		(53,168)		—
Payments of cash dividends		(7,192)		(7,884)
Proceeds from the exercise of stock options		66		1,023
Net cash used in financing activities		(60,294)		(6,861)

EFFECTS OF EXCHANGE RATE CHANGES ON CASH		(4,420)		(483)
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS		(207,128)		84,744
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD		350,472		366,671
CASH AND CASH EQUIVALENTS, END OF PERIOD	$	143,344	$	451,415

SUPPLEMENTAL CASH FLOW INFORMATION (see Notes 7 and 10)

The accompanying notes are an integral part of these condensed consolidated financial statements.

ARGAN, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

July 31, 2022

(Tabular dollar amounts in thousands, except per share data)

(Unaudited)

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 United States (the “U.S.”), the Republic of Ireland (“Ireland”) and the United Kingdom (the “U.K.”). GPS and APC, including a consolidated variable interest entity (“VIE”), 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.

Basis of Presentation and Significant Accounting Policies

The condensed consolidated financial statements include the accounts of Argan, its wholly-owned subsidiaries and the VIE. All significant inter-company balances and transactions have been eliminated in consolidation.

In Note 14, 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. The condensed consolidated balance sheet as of July 31, 2022, the condensed consolidated statements of earnings and stockholders’ equity for the three and six months ended July 31, 2022 and 2021, and the condensed consolidated statements of cash flows for the three and six months ended July 31, 2022 and 2021 are unaudited. The condensed consolidated balance sheet as of January 31, 2022 has been derived from audited financial statements. These condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the U.S. Securities and Exchange Commission (the “SEC”). Certain information and note disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) have been condensed or omitted pursuant to those rules and regulations, although the Company believes that the disclosures made are adequate to make the information not misleading. The accompanying condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements, the notes thereto, and the independent registered public accounting firm’s report thereon, that are included in the Company’s Annual Report on Form 10-K for the fiscal year ended January 31, 2022 (“Fiscal 2022”).

In the opinion of management, the accompanying condensed consolidated financial statements contain all adjustments, which are of a normal and recurring nature, considered necessary to present fairly the financial position of the Company as of July 31, 2022, and its earnings and cash flows for the interim periods presented. The results of operations for any interim period are not necessarily indicative of the results of operations for any other interim period or for a full fiscal year.

Accounting Policies

There are no recently issued accounting pronouncements that have not yet been adopted that the Company considers material to its condensed consolidated financial statements.

Fair Values

The carrying value amounts presented in the condensed 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.

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. 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. 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. Accordingly, the Company 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.

NOTE 2 – REVENUES FROM CONTRACTS WITH CUSTOMERS

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,

Determine the transaction price of the contract,

Allocate the transaction price to the performance obligations, and

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.

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 amounts retained by project owners under construction contracts at July 31, 2022 and January 31, 2022 were $43.6 million and $40.4 million, respectively.

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 includes in the corresponding transaction price an estimate of the amount that it expects to receive from a claim based on management’s judgement regarding all reasonably available information. Once a final amount has been determined, the transaction price will be revised again to reflect the final resolution. At July 31, 2022 and January 31, 2022, the aggregate amounts of such contract variations included in the transaction prices that were still pending customer acceptance were $4.3 million and $7.5 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.

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 July 31, 2022, the Company had RUPO of $372.0 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 51% of the RUPO amount at July 31, 2022 will be included in the amount of consolidated revenues that will be recognized during the remainder of the fiscal year ending January 31, 2023 (“Fiscal 2023”). Most of the remaining amount of the RUPO amount at July 31, 2022 is expected to be recognized in revenues during the fiscal year ending January 31, 2024 (“Fiscal 2024”). Revenues for future periods will also include customer contract amounts added to RUPO subsequent to July 31, 2022.

It is important to note that estimates may be changed in the future and that cancellations, deferrals, or scope adjustments may occur related to work included in the amount of RUPO at July 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 the three and six months ended July 31, 2022 and 2021, disaggregated by the geographic area where the corresponding projects were located:


	Three Months Ended July 31,				Six Months Ended July 31,
	2022		2021		2022		2021
United States	$	93,949	$	123,380	$	174,221	$	238,871
Republic of Ireland		15,532		7,556		25,186		12,249
United Kingdom		8,629		1,630		18,980		7,787
Other		—		442		—		442
Consolidated Revenues	$	118,110	$	133,008	$	218,387	$	259,349

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 14 to the condensed consolidated financial statements.

NOTE 3 – CASH, CASH EQUIVALENTS AND SHORT-TERM INVESTMENTS

At July 31, 2022 and January 31, 2022, certain amounts of cash equivalents were invested in 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. 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 July 31, 2022 and January 31, 2022 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. Interest income is recorded when earned and is included in other income. At July 31, 2022 and January 31, 2022, the weighted average annual interest rates of the outstanding CDs were 0.9% and 0.1%, 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 CDs and the cash deposited with the Bank and cash balances maintained at financial institutions in Ireland and the U.K., in excess of government-insured levels, represent material risks.

NOTE 4 – 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. The amounts of any credit losses for the three and six months ended July 31, 2022 and 2021 were insignificant. The amount of the allowance for credit losses at both July 31, 2022 and January 31, 2022 was $2.4 million.

NOTE 5 – PURCHASED INTANGIBLE ASSETS

At both July 31, 2022 and January 31, 2022, the goodwill balances related primarily to GPS and TRC were $18.5 million and $9.5 million, respectively. Management does not believe that any events or circumstances that have occurred or arisen since January 31, 2022, require an updated assessment of the goodwill balances of either GPS or TRC.

The Company’s purchased intangible assets, other than goodwill, related primarily to TRC and consisted of the following elements as of July 31, 2022 and January 31, 2022:


		July 31, 2022						January 31,
	Estimated	Gross		Accumulated		Net		2022, (net
	Useful Life	Amounts		Amortization		Amounts		amounts)

Trade name	15 years	$	4,499	$	2,000	$	2,499	$	2,650
Process certifications	7 years		1,897		1,807		90		226
Customer relationships	10 years		916		610		306		351
Customer contracts	< 1 year		114		68		46		95
Totals		$	7,426	$	4,485	$	2,941	$	3,322

NOTE 6 – 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 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 July 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 $15.1 million in support of the activities of APC under existing customer contracts. In connection with the project development activities of the VIE that is described in Note 1, the Bank issued a letter of credit, outside the scope of the Credit Agreement, in the approximate amount of $3.4 million as of July 31, 2022 and January 31, 2022, for which the Company has provided cash collateral. As of July 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 comply with certain financial covenants at its fiscal year-end and at each of its fiscal quarter-ends. The Credit Agreement 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 July 31, 2022 and January 31, 2022, 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 7 – COMMITMENTS

Leases

The Company’s leases are primarily operating leases that cover office space, expiring 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 may be embedded in broader agreements with subcontractors or construction equipment suppliers. The Company has no material finance leases. None of the operating leases include 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.

Operating lease expense amounts are recorded on a straight-line basis over the expected lease terms and were $0.5 million and $1.3 million for the three and six months ended July 31, 2022, respectively, and were $1.1 million and $1.9 million for the three and six months ended July 31, 2021, respectively. Operating lease payments for the three and six months ended July 31, 2022 were $0.5 million and $1.3 million, respectively, and they were $1.1 million and $1.9 million for the three and six months ended July 31, 2021, respectively. For operating leases as of July 31, 2022, the weighted average lease term is 60 months and the weighted average discount rate is 2.4%. The aggregate amounts of operating leases added during the six months ended July 31, 2022 and 2021 were $0.5 million and $0.8 million, respectively.

The following is a schedule of future minimum lease payments for the operating leases that were recognized in the condensed consolidated balance sheet as of July 31, 2022.


Years Ending January 31,
2023 (remainder)	$	640
2024		540
2025		380
2026		250
2027		231
Thereafter		1,025
Total lease payments		3,066
Less interest portion		182
Present value of lease payments		2,884
Less current portion (included in accrued expenses)		894
Non-current portion (included in noncurrent liabilities)	$	1,990

Payments for the occupancy by TRC of its primary offices and plant, which are made to the founder and retired chief executive officer of TRC based on an annual rental rate of $0.5 million, are being made on a month-to-month rental basis.

The Company also uses equipment and occupies other facilities under short-term rental agreements. Rent expense amounts incurred under short-term rental agreements were $3.0 million and $5.3 million, respectively for the three and six months ended July 31, 2022. Rent expense amounts incurred under these types of arrangements for the three and six months ended July 31, 2021 was $2.5 million and $4.9 million, respectively.

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 July 31, 2022 are not estimable.

As of July 31, 2022, the value of the Company’s unsatisfied bonded performance obligations, covering all of its subsidiaries, was approximately $139.6 million. In addition, as of July 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; these bonds expire at various dates over the next two years. Not all of our projects require bonding.

As of July 31, 2022 and January 31, 2022, the Company had 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. A liability was established for the estimated loss related to this guarantee during Fiscal 2022.

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 condensed consolidated balances sheets. The liability amounts may be periodically adjusted to reflect changes in the estimated size and number of expected warranty claims.

NOTE 8 – 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 are expected to have a material adverse effect on the condensed consolidated financial statements as of July 31, 2022.

NOTE 9 – 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 replaced 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.”

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 awards are documented in a written agreement between the Company and the awardee. All stock options awarded under the Stock Plans have exercise prices per share at least equal to the common stock’s market value on the date of grant. Stock options 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 July 31, 2022, there were 1,963,635 shares of common stock reserved for issuance under the Stock Plans; this number includes 252,146 shares of common stock available for future awards under the 2020 Plan.

Stock Options

A summary of stock option activity under the Stock Plans for the six months ended July 31, 2022, along with corresponding weighted average per share amounts, is presented below (shares in thousands):


		Exercise		Remaining
	Shares	Price		Term (years)	Fair Value
Outstanding, February 1, 2022	1,405	$	44.35	6.17	$	10.31
Granted	38	$	36.78
Exercised	(2)	$	32.68
Forfeited	(10)	$	56.27
Outstanding, July 31, 2022	1,431	$	44.08	5.79	$	10.19
Exercisable, July 31, 2022	1,192	$	44.83	5.27	$	10.74

Outstanding, July 31, 2021	1,398	$	44.42	6.51	$	10.41
Exercisable, July 31, 2021	1,022	$	45.34	5.76	$	11.20

The changes in the number of non-vested options to purchase shares of common stock for the six months ended July 31, 2022, and the weighted average fair value per share for each number, are presented below (shares in thousands):


	Shares	Fair Value
Non-vested, February 1, 2022	295	$	7.80
Granted	38	$	6.68
Vested	(94)	$	8.24
Non-vested, July 31, 2022	239	$	7.45

Non-vested, July 31, 2021	376	$	8.27

The total intrinsic value amount of the stock options exercised during the six months ended July 31, 2021 was $0.3 million; the amount was not significant for the six months ended July 31, 2022. At July 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 $0.5 million and $0.3 million, respectively.

Restricted Stock Units

The Company awards restricted stock units to senior executives, members of the Company’s board of directors and certain other employees. Awardees earn the right to receive shares of common stock as certain performance goals are achieved and/or service periods are satisfied. Each restricted stock unit expires on the three-year anniversary of the award.

During the six months ended July 31, 2022, the Company awarded 47,000 performance-based restricted stock units, 7,500 renewable performance-based restricted stock units, 60,000 time-based restricted stock units and 2,604 shares based on the amount of cash dividends deemed paid on shares earned pursuant to the awards. During the six months ended July 31, 2021, the Company awarded 49,000 performance-based restricted stock units, 10,000 renewable performance-based restricted stock units and 49,500 time-based restricted stock units.

The changes in the maximum number of restricted stock units for the six months ended July 31, 2022, and the weighted average fair value per share for each number, are presented below (shares in thousands):


	Shares	Fair Value
Outstanding, February 1, 2022	222	$	31.48
Awarded	117	$	26.97
Issued	(37)	$	38.51
Forfeited	(22)	$	40.85
Outstanding, July 31, 2022	280	$	29.46

Outstanding, July 31, 2021	190	$	29.73

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 $1.1 million and $0.9 million for the three months ended July 31, 2022 and 2021, respectively. Expense amounts related to stock awards were $2.0 million and $1.6 million for the six months ended July 31, 2022 and 2021, respectively. At July 31, 2022, there was $7.5 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, 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 (which is 50% of the maximum number) of shares on the award date. For the renewable performance-based restricted stock units, 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 10 – INCOME TAXES

Income Tax Expense Reconciliations

The Company’s income tax amounts for the six months ended July 31, 2022 and 2021 differed from corresponding amounts computed by applying the federal corporate income tax rate of 21% to the income before income taxes for the periods as presented below:


	Six Months Ended July 31,
	2022		2021
Computed expected income tax expense	$	(4,970)	$	(6,635)
Difference resulting from:
State income taxes, net of federal tax effect		(349)		(719)
Research and development credits adjustment		(6,181)		—
Deferred tax adjustments		(66)		(283)
Other permanent differences and adjustments, net		(393)		(322)
Income tax expense	$	(11,959)	$	(7,959)

Foreign income tax expense amounts for the six months ended July 31, 2022 and 2021 were not material.

Net Operating Loss (“NOL”) Carryback

In an effort to combat the adverse economic impacts of the COVID-19 crisis, the U.S. 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 the year ended January 31, 2020 (“Fiscal 2020”), which was approximately $39.5 million. The Company made the appropriate filing with the Internal Revenue Service (the “IRS”) requesting carryback refunds of income taxes paid for the years ended January 31, 2017 (“Fiscal 2017”), 2016 (“Fiscal 2016”) and 2015 in the total amount of approximately $12.7 million during the fiscal year ended January 31, 2021 (“Fiscal 2021”); the IRS has not completed the processing of the Company’s refund request.

Research and Development Tax Credits

During the year ended January 31, 2019 (“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 net amount of federal and state 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. The Company recorded a corresponding liability for uncertain income tax return positions related to identified but unrecognized research and development tax credit benefits in the amount of $5.0 million. Most of this liability was included in accrued expenses as of January 31, 2022.

During Fiscal 2021, the IRS concluded examinations of the Company’s consolidated federal income tax returns for Fiscal 2016, as amended; Fiscal 2017, as amended; and the year ended January 31, 2018 (“Fiscal 2018”) with its focus on the research and development tax credits included therein.

In January 2021, the IRS issued its final revenue agents reports that documented its understanding of the facts, attempted to summarize the Company’s arguments in support of the research and development claims and stated its position which disagreed with the Company’s treatment of a substantial amount of the costs that supported the Company’s claims. In March 2021, the Company submitted a formal protest of the findings of the IRS examiner and requested an appeals hearing.

At the conclusion of the hearing that occurred in May 2022, the Company agreed to accept a settlement offer from the IRS in the amount of approximately $7.9 million, before interest. As a result, during the three-month period ended July 31, 2022, the Company made an unfavorable adjustment to its liability for uncertain income tax positions in the approximate amount of $6.2 million. This amount is also included in income tax expense for the three and six months ended July 31, 2022.

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 any unfavorable adjustments related to the ultimate settlement of the income tax disputes with the states will not be significant.

Income Tax Refunds

As of July 31, 2022 and January 31, 2022, the balances of other current assets in the condensed consolidated balance sheet included income tax refunds receivable and prepaid income taxes in the total amounts of approximately $14.9 million and $29.5 million, respectively. The income tax refunds included the amounts that were expected to be received from the IRS upon completion of the tax return examination appeals process and the amount expected to be received from the IRS upon its processing of the Company’s NOL carryback refund request as described above.

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 the end of Fiscal 2018 except for several notable exceptions including Ireland, the U.K. and several states where the open periods are one year longer.

Solar Energy Projects

The Company has invested in limited liability companies that make equity investments in solar energy projects that are eligible to receive energy tax credits, including $4.1 million that was invested during the six months ended July 31, 2021. The passive investments have been accounted for using the equity method and the balances are included in other assets in our condensed 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. Investment tax credits in the approximate amount of $3.0 million were recognized during the six months ended July 31, 2021. At July 31, 2022 and January 31, 2022, the investment account balances were $1.2 million and $0.2 million, respectively. These investments are expected to provide positive overall returns over their six-year expected lives.

During the three and six months ended July 31, 2022, the investment balance was adjusted to reflect the Company’s share of the income of the investment entities in the amounts of approximately $0.5 million and $1.0 million, respectively, which amounts have been included as other income in the Company’s condensed consolidated statements of earnings for the corresponding periods.

The Company has also established deferred taxes related to the difference in the book and tax bases of the investments.

Supplemental Cash Flow Information

The amounts of cash paid for income taxes during the six months ended July 31, 2022 and 2021 were $1.3 million and $7.5 million (including the $4.1 million solar energy investment described above), respectively. The amounts of income tax refunds received during the six months ended July 31, 2022 and 2021 were not material.

NOTE 11 – NET INCOME PER SHARE

Basic and diluted net income per share amounts are computed as follows (shares in thousands except in the note):


	Three Months Ended July 31,
	2022		2021

Net income	$	4,222	$	12,870

Weighted average number of shares outstanding – basic		14,134		15,769
Effect of stock awards ⁽¹⁾		113		213
Weighted average number of shares outstanding – diluted		14,247		15,982

Net income per share
Basic	$	0.30	$	0.82
Diluted	$	0.30	$	0.81

(1)

For the three months ended July 31, 2022 and 2021, the weighted average numbers of shares determined on a dilutive basis exclude the effects of antidilutive stock options covering an aggregate of 876,734 and 366,500 shares of common stock, respectively.


	Six Months Ended July 31,
	2022		2021

Net income	$	11,707	$	23,636

Weighted average number of shares outstanding – basic		14,516		15,748
Effect of stock awards ⁽¹⁾		100		230
Weighted average number of shares outstanding – diluted		14,616		15,978

Net income per share
Basic	$	0.81	$	1.50
Diluted	$	0.80	$	1.48

(1)

For the six months ended July 31, 2022 and 2021, the weighted average numbers of shares determined on a dilutive basis exclude the effects of antidilutive stock options covering an aggregate of 876,734 and 366,500 shares of common stock, respectively.

NOTE 12 – CASH DIVIDENDS AND COMMON STOCK REPURCHASES

On June 21, 2022, Argan’s board of directors declared a regular quarterly cash dividend in the amount of $0.25 per share of common stock, which was paid on July 29, 2022 to stockholders of record at the close of business on July 21, 2022. On April 11, 2022, Argan’s board of directors declared a regular quarterly cash dividend in the amount of $0.25 per share of common stock, which was paid on April 29, 2022 to stockholders of record at the close of business on April 21, 2022. During the six months ended July 31, 2021, the board of directors declared two regular quarterly cash dividends, each in the amount of $0.25 per share of common stock, which were paid to stockholders on July 30, 2021 and April 30, 2021, respectively.

Pursuant to authorizations provided by Argan’s board of directors (the “Share Repurchase Plan”), the Company repurchased shares of its common stock during the six months ended July 31, 2022. During this period, the Company repurchased 1,412,592 shares of common stock, most on the open market, for an aggregate price of approximately $53.2 million, or $37.64 per share.

NOTE 13 – CUSTOMER CONCENTRATIONS

The majority of the Company’s consolidated revenues relate to performance by the power industry services segment which provided 77% and 74% of consolidated revenues for the three months ended July 31, 2022 and 2021, respectively, and 76% of consolidated revenues for both the six months ended July 31, 2022 and 2021. The industrial services segment represented 20% and 23% of consolidated revenues for the three months ended July 31, 2022 and 2021, respectively, and 21% and 22% of consolidated revenues for the six months ended July 31, 2022 and 2021, respectively.

The Company’s most significant customer relationships for the three months ended July 31, 2022 included two power industry service customers, which accounted for 47% and 10% of consolidated revenues, respectively. The Company’s most significant customer relationships for the three months ended July 31, 2021 included one power industry service customer and one industrial services customer, which accounted for 59% and 12% of consolidated revenues, respectively. The Company’s most significant customer relationship for the six months ended July 31, 2022 included one power industry service customer, which accounted for 47% of consolidated revenues. The Company’s most significant customer relationships for the six months ended July 31, 2021 included one power industry service customer and one industrial services customer, which accounted for 63% and 12% of consolidated revenues, respectively.

The accounts receivable balances from two major customers represented 17% and 10% of the corresponding consolidated balance as of July 31, 2022. Accounts receivable balances from three major customers represented 22%, 15% and 12% of the corresponding consolidated balance as of January 31, 2022. The contract asset balance related to one major customer represented 14% of the corresponding consolidated balance as of July 31, 2022. Contract asset balances from two major customers represented 31% and 13% of the corresponding consolidated balance as of January 31, 2022.

NOTE 14 – 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 the three and six months ended July 31, 2022, intersegment revenues were not material. For the three and six months ended July 31, 2021, intersegment revenues were $1.2 million and $3.2 million, respectively, and primarily related to services provided by industrial fabrication and field services 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 the three and six months ended July 31, 2022 and 2021. The “Other” column in each summary includes the Company’s corporate expenses.


Three Months Ended	Power		Industrial		Telecom
July 31, 2022	Services		Services		Services		Other		Totals
Revenues	$	91,327	$	23,022	$	3,761	$	—	$	118,110
Cost of revenues		71,225		19,551		2,947		—		93,723
Gross profit		20,102		3,471		814		—		24,387
Selling, general and administrative expenses		6,058		1,685		808		2,433		10,984
Income (loss) from operations		14,044		1,786		6		(2,433)		13,403
Other income (expense), net		437		—		(1)		69		505
Income (loss) before income taxes	$	14,481	$	1,786	$	5	$	(2,364)		13,908
Income tax expense										(9,686)
Net income									$	4,222

Amortization of intangibles	$	—	$	165	$	68	$	—	$	233
Depreciation		138		508		100		1		747
Property, plant and equipment additions		42		336		22		—		400

Current assets	$	258,771	$	31,960	$	4,745	$	82,717	$	378,193
Current liabilities		124,320		15,055		1,991		646		142,012
Goodwill		18,476		9,467		90		—		28,033
Total assets		282,783		49,097		8,198		82,992		423,070


Three Months Ended	Power		Industrial		Telecom
July 31, 2021	Services		Services		Services		Other		Totals
Revenues	$	99,004	$	30,153	$	3,851	$	—	$	133,008
Cost of revenues		78,496		23,847		3,013		—		105,356
Gross profit		20,508		6,306		838		—		27,652
Selling, general and administrative expenses		5,751		1,977		484		2,119		10,331
Income (loss) from operations		14,757		4,329		354		(2,119)		17,321
Other income (expense), net		(262)		—		—		2		(260)
Income (loss) before income taxes	$	14,495	$	4,329	$	354	$	(2,117)		17,061
Income tax expense										(4,191)
Net income									$	12,870

Amortization of intangibles	$	61	$	164	$	—	$	—	$	225
Depreciation		153		593		112		1		859
Property, plant and equipment additions		35		7		123		2		167


Current assets	$	389,998	$	29,084	$	3,751	$	174,823	$	597,656
Current liabilities		293,002		12,099		1,563		683		307,347
Goodwill		18,476		9,467		—		—		27,943
Total assets		422,902		48,655		5,274		175,158		651,989


Six Months Ended	Power		Industrial		Telecom
July 31, 2022	Services		Services		Services		Other		Totals
Revenues	$	165,276	$	45,523	$	7,588	$	—	$	218,387
Cost of revenues		130,260		38,231		5,771		—		174,262
Gross profit		35,016		7,292		1,817		—		44,125
Selling, general and administrative expenses		11,673		3,444		1,573		4,869		21,559
Income (loss) from operations		23,343		3,848		244		(4,869)		22,566
Other income (expense), net		1,021		—		1		78		1,100
Income (loss) before income taxes	$	24,364	$	3,848	$	245	$	(4,791)		23,666
Income tax expense										(11,959)
Net income									$	11,707

Amortization of intangibles	$	—	$	331	$	68	$	—	$	399
Depreciation		280		1,052		222		2		1,556
Property, plant and equipment additions		94		487		57		—		638


Six Months Ended	Power		Industrial		Telecom
July 31, 2021	Services		Services		Services		Other		Totals
Revenues	$	196,176	$	56,811	$	6,362	$	—	$	259,349
Cost of revenues		157,165		45,816		5,002		—		207,983
Gross profit		39,011		10,995		1,360		—		51,366
Selling, general and administrative expenses		11,206		3,859		970		4,188		20,223
Income (loss) from operations		27,805		7,136		390		(4,188)		31,143
Other income (expense), net		448		—		—		4		452
Income (loss) before income taxes	$	28,253	$	7,136	$	390	$	(4,184)		31,595
Income tax expense										(7,959)
Net income									$	23,636

Amortization of intangibles	$	122	$	331	$	—	$	—	$	453
Depreciation		319		1,200		220		2		1,741
Property, plant and equipment additions		637		16		355		3		1,011

ITEM 2. 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 July 31, 2022, and the results of their operations for the three and six month periods ended July 31, 2022 and 2021, 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 Fiscal 2022 that was filed with the SEC on April 13, 2022 (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,” “estimate,” “foresee,” “should,” “would,” “could,” or other similar expressions are intended to identify forward-looking statements.

Our forward-looking statements, 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 market, including the renewable energy sector, for a wide range of customers, including independent power project owners, public utilities, global energy plant construction firms and other commercial firms with significant power requirements. 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 significant acquired companies 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 the three months ended July 31, 2022 were $118.1 million, which represented a decrease of $14.9 million, or 11.2%, from consolidated revenues of $133.0 million reported for the three months ended July 31, 2021.

The revenues of the power industry services segment decreased by $7.7 million to $91.3 million for the three months ended July 31, 2022, from $99.0 million reported for the three months ended July 31, 2021. The revenues of this reportable segment of our business represented 77.3% and 74.4% of corresponding consolidated revenues for the three months ended July 31, 2022 and 2021, respectively. The industrial services business reported revenues of $23.0 million for the three months ended July 31, 2022. This amount represented a decrease of $7.1 million, or 23.6%, from revenues of $30.2 million reported by TRC for the three months ended July 31, 2021. Revenues provided by this reportable business segment represented 19.5% and 22.7% of corresponding consolidated revenues for the three months ended July 31, 2022 and 2021, respectively.

Despite the reductions in revenues for the three months ended July 31, 2022, we maintained our overall gross profit percentage. Consolidated gross profit for the three-month period ended July 31, 2022 was $24.4 million, or 20.6% of the corresponding consolidated revenues, which reflected favorable contributions from all three reportable business segments. For the three-month period ended July 31, 2021, the consolidated gross profit was $27.7 million, which represented approximately 20.8% of the corresponding amount of consolidated revenues.

Selling, general and administrative expenses for the three months ended July 31, 2022 and 2021 were $11.0 million, or 9.3% of corresponding consolidated revenues, and $9.9 million, or 7.8% of corresponding consolidated revenues, respectively.

Consolidated revenues for the six months ended July 31, 2022 were $218.4 million, which represented a decrease of $40.9 million, or 15.8%, from consolidated revenues of $259.3 million reported for the six months ended July 31, 2021.

The revenues of power industry services decreased by $30.9 million to $165.3 million for the six months ended July 31, 2022, from $196.2 million reported for the six months ended July 31, 2021. The revenues of this reportable segment of our business represented 75.7% and 75.6% of corresponding consolidated revenues for the six months ended July 31, 2022 and 2021, respectively. The industrial services business reported revenues of $45.5 million for the six months ended July 31, 2022. This amount represented a decrease of $11.3 million, or 19.9%, from revenues of $56.8 million reported by TRC for the six months ended July 31, 2021. Revenues provided by this reportable business segment represented 20.8% and 21.9% of corresponding consolidated revenues for the six months ended July 31, 2022 and 2021, respectively.

Consolidated gross profit for the six-month period ended July 31, 2022 was $44.1 million, or 20.2% of the corresponding consolidated revenues, which also reflected favorable contributions from all three reportable business segments. For the six-month period ended July 31, 2021, the consolidated gross profit was $51.4 million, which represented approximately 19.8% of the corresponding amount of consolidated revenues.

Selling, general and administrative expenses for the six months ended July 31, 2022 and 2021 were $21.6 million, or 9.9% of corresponding consolidated revenues, and $20.2 million, or 7.8% of corresponding consolidated revenues, respectively.

Due substantially to the unfavorable income tax expense adjustment recorded during the three months ended July 31, 2022 in the approximate amount of $6.2 million related to the settlement of claims with the IRS as discussed in Note 10 to our accompanying condensed consolidated financial statements, income tax expense increased to $9.7 million for the quarter from $4.2 million for the three months ended July 31, 2021. Likewise, the amount of this adjustment was the most significant component of income tax expense for the six months ended July 31, 2022, which was $12.0 million. Income tax expense for the six months ended July 31, 2021 was $8.0 million.

Excluding the effect of the IRS settlement adjustment, our effective income tax rates for the three and six months ended July 31, 2022 were 25.2% and 24.4%, respectively. For the three and six months ended July 31, 2021, our effective income tax rates were 24.6% and 25.2%, respectively.

For the three months ended July 31, 2022, our overall operating profit performance resulted in net income in the amount of $4.2 million, or $0.30 per diluted share. For the comparable period last year, we reported net income in the amount of $12.9 million, or $0.81 per dilutive share. For the six months ended July 31, 2022 and 2021, net income was $11.7 million, or $0.80 per diluted share, and $23.6 million, or $1.48 per diluted share. The unfavorable income tax expense adjustment identified above reduced net income per diluted share for the three and six months ended July 31, 2022 by $0.43 and $0.42, respectively.

Engineering, Procurement and Construction Service Contracts

At July 31, 2022, our consolidated project backlog amount of $0.7 billion substantially consisted of the projects of the power industry services reporting segment. The comparable backlog amount as of January 31, 2022 was also $0.7 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 2 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 July 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 near the end of Fiscal 2023. We continue to pursue natural gas-fired power plant, renewable energy plant and industrial construction opportunities in the U.S., Ireland and the U.K., and we expect to announce the commencement of a meaningful new EPC services contract in the third quarter. However, it is important to note that the start of new projects is primarily controlled by project owners and that delays may occur that are beyond our control.

We are committed to the construction of state-of-the-art, natural gas-fired power plants, which represents our core business, as important elements of our country’s electricity-generation mix in the future. In addition, 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 renewable and other industrial projects in order to diversify the sources of revenues. 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 Competitive Power Ventures, Inc., 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 first half of Fiscal 2024. The unique Maple Hill Solar project, which is located in Cambria County, is being 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. A 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, referred to as the “Kilroot” project, is being developed by EPNI Energy Limited. Full project activities are underway; the overall completion of this project is expected to occur in the latter half of Fiscal 2024.

In May 2022, APC entered into engineering and construction services contracts with Ireland’s Electricity Supply Board (“ESB”) to construct three 65 MW aero-derivative gas turbine flexible generation power plants in and around Dublin, Ireland. Two of the power plants, the Poolbeg and Ringsend FlexGen Power Plants, will be located on the Poolbeg Peninsula, and the Corduff FlexGen Power Plant will be built in Goddamendy. All three projects cleared the applicable capacity auction earlier this year and are expected to operate intermittently during peak periods of electricity demand and as back-up supply options when renewable electricity generation is limited. A full notice to proceed has been received and project activities have commenced. The completion of each power plant is expected to occur near the end of Fiscal 2024.

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 net electricity generation. For 2021, coal fueled 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.

In the reference case of its Annual Energy Outlook 2022, the Energy Information Administration (“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.

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. The pace of the historic increase in the preference for natural gas as an electricity generating fuel source also 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. 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. Additionally, lenders, who have become more wary of funding oil-related ventures as environmental, social and governance ideas catch on in financial circles, are generally unwilling to provide capital for energy projects to increase the domestic production and transmission of oil and natural gas.

We believe that 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. These policy stances have continued during the invasion of Ukraine and the current year rise in oil prices as the administration makes appeals to other countries to increase oil production while domestic production is challenged by supply chain and labor issues and the maintenance of restrictive regulations. Meanwhile, delays continue for the construction of pipelines needed to transport natural gas to liquid natural gas export facilities for shipment to Western Europe.

In August 2022, President Biden signed the Inflation Reduction Act, a climate and healthcare bill that imposes new taxes on corporations with net profits for financial reporting in excess of $1.0 billion, spends billions over a decade on new workers and technology at the IRS, and funds hundreds of billions in tax subsidies intended to combat climate change among other measures. According to certain commentary, the legislation will cause investment in technologies needed for leaner production and use of fuel types, including hydrogen, nuclear, renewables and fossil fuels. However, it appears that receipt of the tax subsidies will be conditioned on the extent that taxpayers “buy American” and/or pay prevailing wages. Existing supply chains may lack the capacity to meet the demand that the incentives are intended to create. Therefore, the subsidies may not provide the intended economic incentives to renewable project owners. Further, it is not clear that the legislation will provide assistance to current and future project owners of fossil-fuel power projects.

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 and other energy storage technologies) 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 were scheduled to decline and then expire early in the next decade, the wind capacity additions may 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.

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. However, reductions in production levels during the pandemic, an increase in the amount of liquid natural gas exports and heat-wave temperatures throughout the U.S., among other factors including the invasion of Ukraine, are straining domestic natural gas supplies and forcing prices upwards. As a result, the price of natural gas in the U.S. has increased meaningfully since the beginning of the calendar year and may continue to increase throughout the remainder of 2022.

Most of our recently completed and awarded EPC service contracts relate to the construction of natural gas-fired power plants located within the Mid-Atlantic geographic footprint of the electric power system operated by PJM, which includes all or part of thirteen states and the District of Columbia. 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. Capacity payments represent meaningful portions of the revenue streams of qualifying power plants. A capacity auction for a particular delivery year is usually held during the month of May, three years prior to the actual delivery year. However, the 2023/2024 auction, scheduled for December 2021, was postponed until January 2022 and then was postponed again until June 2022. The auction results included increased capacity powered by nuclear, solar and natural gas energy sources, and decreased capacity provided by coal and wind energy sources. However, prices for the 2023/2024 delivery year were significantly lower than for the previous auction.

These are unfavorable trends that challenge power plant developers, especially in the PJM grid area, as they assess new power plant opportunities.

Nevertheless, we believe that 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, generally cost-effective and reliable. 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. We believe that its benefits as a source of power are compelling, especially as a complement to the deployment of wind and solar powered energy sources and 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. The future availability of less carbon-intense and higher efficiency natural gas in the U.S. should 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 due to the challenges described above.

Throughout the U.S., the risk of electricity shortages is rising as traditional power plants are being retired more quickly than they can be replaced by renewable energy and battery storage. Power grids are feeling the strain as the U.S. makes the historic transition from conventional power plants fueled by coal and natural gas to cleaner forms of energy such as wind and solar power, and aging nuclear plants are slated for retirement. Electric-grid operators are warning that power-generating capacity is struggling to keep up with demand, a gap that could lead to additional rolling blackouts during heat waves or other peak periods.

The challenge is that wind and solar farms do not produce electricity at all times and need large batteries to store their output for later use. While large battery storage capacity is under development, regional grid operators have lately warned that the pace may not be fast enough to offset the closures of traditional power plants that can work around the clock.

Accelerating the build-out of renewable energy sources and batteries has become an especially difficult proposition amid supply-chain challenges and inflation. For example, earlier this year, the highly publicized probe by the U.S. Commerce Department into whether Chinese solar manufacturers are circumventing trade tariffs on solar panels had the effect of halting imports of key components needed to build new solar farms and effectively brought the U.S. solar industry to a temporary standstill, although work at our solar energy project in Pennsylvania continued.

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 complexities, transmission planning and federal permitting processes. Further, U.S. projects are confronted by shipping regulations that may limit the ability of developers to replicate successful European erection models. Proponents of clean energy also face political challenges from constituencies who oppose the impacts to wildlife and the environment that may be caused by clean energy infrastructure projects.

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.

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 clean-air concerns. 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 or the wind is not blowing, for extended periods of time and without certain harmful air emissions.

It has been stated that the current scramble for electricity, regardless of source, caused by Russia’s invasion of Ukraine has clarified that the 100% transition to renewable energy is in the distant future and has caused, in part, renewed interest in not only carbon capture techniques, but carbon removal technologies as well. Carbon capture processes grab carbon from smokestacks and other sources of dense greenhouse gases, thereby reducing harmful emissions. Carbon-removal technologies are more demanding as they suck carbon out of the more diffuse open air in order to store it for centuries. Governments, including the U.S., are taking initial steps to boost this industry. The success of this industry could reduce the climate-change fear associated with natural gas-fired power plants.

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, overseas power markets provide important new power construction opportunities for us especially across Ireland and the U.K.

While both of these 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 the significant Kilroot project 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 2022/2023 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.

Last year, the Irish government 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 battery storage and generation from renewable gases. 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.

As noted above, APC recently entered into engineering and construction services contracts with the ESB to construct three 65 MW aero-derivative gas turbine flexible generation power plants in and around Dublin, Ireland. All three projects are expected to operate intermittently during peak periods of electricity demand and as back-up supply options when renewable electricity generation is limited. A full notice to proceed has been received and project activities have commenced. 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. 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. Currently, APC is completing a project to install natural gas-fired power generation for a major data center in the Dublin area.

In our 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 the Company.

APC is actively pursuing other 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 other projects and APC is confident that it 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 a biomass-burning power plant and won the awards of the projects to build new gas-fired power plant units near Belfast and Dublin. 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 will work together in the future are becoming more substantive 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 Ireland and the U.K. that APC is positioned and has the capability to build larger and more complex power projects.

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 Three Months Ended July 31, 2022 and 2021

We reported net income of $4.2 million, or $0.30 per diluted share, for the three months ended July 31, 2022. For the comparable period of the prior year, we reported net income of $12.9 million, or $0.81 per diluted share.

The following schedule compares our operating results for the three months ended July 31, 2022 and 2021 (dollars in thousands):


	Three Months Ended July 31,
	2022		2021		$ Change		% Change
REVENUES
Power industry services	$	91,327	$	99,004	$	(7,677)	(7.8)	%
Industrial fabrication and field services		23,022		30,153		(7,131)	(23.6)
Telecommunications infrastructure services		3,761		3,851		(90)	(2.3)
Revenues		118,110		133,008		(14,898)	(11.2)
COST OF REVENUES
Power industry services		71,225		78,496		(7,271)	(9.3)
Industrial fabrication and field services		19,551		23,847		(4,296)	(18.0)
Telecommunications infrastructure services		2,947		3,013		(66)	(2.2)
Cost of revenues		93,723		105,356		(11,633)	(11.0)
GROSS PROFIT		24,387		27,652		(3,265)	(11.8)
Selling, general and administrative expenses		10,984		10,331		653	6.3
INCOME FROM OPERATIONS		13,403		17,321		(3,918)	(22.6)
Other income (expense), net		505		(260)		765	NM
INCOME BEFORE INCOME TAXES		13,908		17,061		(3,153)	(18.5)
Income tax expense		(9,686)		(4,191)		(5,495)	(131.1)
NET INCOME	$	4,222	$	12,870	$	(8,648)	(67.2)	%

Revenues

Power Industry Services

The revenues of the power industry services segment, representing the businesses of GPS and APC, decreased by 7.8%, or $7.7 million, to $91.3 million for the three months ended July 31, 2022 compared with revenues of $99.0 million for the three months ended July 31, 2021 as the quarterly construction activities associated with the Guernsey Power Station project have passed peak levels. The reduction in revenues between the quarters was partially offset by increasing revenues at several APC projects including the Kilroot Power Station, ESB FlexGen peaker plants and the Equinix data centre project. The revenues of this business segment represented approximately 77.3% of consolidated revenues for the quarter ended July 31, 2022 and 74.4% of consolidated revenues for the corresponding prior year quarter.

The primary driver for the revenues of this segment for the three months ended July 31, 2021 were the revenues associated with the construction of the Guernsey Power Station as the construction activities on this project were at peak levels.

Industrial Fabrication and Field Services

The revenues of our industrial fabrication and field services segment, representing the business of TRC, decreased by $7.1 million, or 23.6%, to $23.0 million for the three months ended July 31, 2022 compared to revenues of $30.2 million for the three months ended July 31, 2021 as the amounts of field services and pipe and vessel fabrication work declined. For the three months ended July 31, 2022 and 2021, the revenues of this segment represented 19.5% and 22.7% of consolidated revenues for the corresponding periods.

TRC’s performance for the three-month period ended July 31, 2021 was particularly strong as it reflected significant increases in revenues earned on field services activities during the period, as well as increases in revenues associated with pipe and vessel fabrication works. The major customers of TRC include some of North America’s largest fertilizer producers, as well as other chemical, mining, forest products, construction and energy companies with plants, facilities and other sites located primarily in the southeastern region of the U.S.

Telecommunications Infrastructure Services

The revenue results of this business segment, which represent the business of SMC, were $3.8 million for the three-month period ended July 31, 2022, a decrease of $0.1 million, or 2.3%, from the amount of revenues earned during the three months ended July 31, 2021.

Cost of Revenues

With the decrease in consolidated revenues for the three months ended July 31, 2022 compared with last year’s second quarter ended July 31, 2021, the consolidated cost of revenues also decreased between the quarters. These costs were $93.7 million and $105.4 million for the three-month periods ended July 31, 2022 and 2021, respectively, representing a decrease of approximately 11.0%.

For the three-month period ended July 31, 2022, we reported a consolidated gross profit of approximately $24.4 million which represented a gross profit percentage of approximately 20.6% of corresponding consolidated revenues. The gross profit percentages of corresponding revenues for the power industry services, industrial services and the telecommunications infrastructure segments were 22.0%, 15.1% and 21.6%, respectively, for the quarter ended July 31, 2022.

Our consolidated gross profit reported for the three-month period ended July 31, 2021 was $27.7 million, which represented a gross profit percentage of approximately 20.8% of corresponding consolidated revenues. The gross profit percentages of corresponding revenues for the power industry services, industrial services and the telecommunications infrastructure segments were 20.7%, 20.9% and 21.8%, respectively, for the quarter ended July 31, 2021.

Selling, General and Administrative Expenses

These costs were $11.0 million and $10.3 million for the three months ended July 31, 2022 and 2021, respectively, representing an increase of $0.7 million between the quarters, or 6.3%.

Other Income (Expense), Net

We reported other income, net, in the amount of $0.5 million for the three months ended July 31, 2022 which included primarily earnings associated with our solar fund investments described in Note 10 to the accompanying condensed consolidated financial statements. We reported other expense, net, in the amount of $0.3 million for the three months ended July 31, 2021, which reflected our share of the net loss reported for the quarter by the solar fund investments.

Income Taxes

We incurred income tax expense for the three months ended July 31, 2022 in the amount of approximately $9.7 million, including an unfavorable adjustment in the approximate amount of $6.2 million that was related to the settlement of the research and development credit claims with the IRS. Excluding the effect of this adjustment, our effective tax rate for the three months ended July 31, 2022 was 25.2%, which differed from the statutory federal tax rate of 21% due primarily to the unfavorable estimated effects of state income taxes and permanent differences, including certain nondeductible executive compensation and global intangible low taxed income (“GILTI”).

For the three months ended July 31, 2021, we reported income tax expense in the amount of approximately $4.2 million, which represented an effective income tax rate of 24.6% for the period. The tax rate differed from the statutory federal tax rate of 21% due primarily to the unfavorable estimated effects of state income taxes and permanent differences, offset partially by the favorable adjustment to deferred taxes related to the difference in the book and tax bases of our investments in solar energy projects.

Comparison of the Results of Operations for the Six Months Ended July 31, 2022 and 2021

We reported net income of $11.7 million, or $0.80 per diluted share, for the six months ended July 31, 2022. For the six months ended July 31, 2021, we reported net income of $23.6 million, or $1.48 per diluted share.

The following schedule compares our operating results for the six months ended July 31, 2022 and 2021 (dollars in thousands):


	Six Months Ended July 31,
	2022		2021		$ Change		% Change
REVENUES
Power industry services	$	165,276	$	196,176	$	(30,900)	(15.8)	%
Industrial fabrication and field services		45,523		56,811		(11,288)	(19.9)
Telecommunications infrastructure services		7,588		6,362		1,226	19.3
Revenues		218,387		259,349		(40,962)	(15.8)
COST OF REVENUES
Power industry services		130,260		157,165		(26,905)	(17.1)
Industrial fabrication and field services		38,231		45,816		(7,585)	(16.6)
Telecommunications infrastructure services		5,771		5,002		769	15.4
Cost of revenues		174,262		207,983		(33,721)	(16.2)
GROSS PROFIT		44,125		51,366		(7,241)	(14.1)
Selling, general and administrative expenses		21,559		20,223		1,336	6.6
INCOME FROM OPERATIONS		22,566		31,143		(8,577)	(27.5)
Other income (expense), net		1,100		452		648	143.4
INCOME BEFORE INCOME TAXES		23,666		31,595		(7,929)	(25.1)
Income tax expense		(11,959)		(7,959)		(4,000)	(50.3)
NET INCOME	$	11,707	$	23,636	$	(11,929)	(50.5)	%

Revenues

Power Industry Services

The revenues of the power industry services segment decreased by 15.8%, or $30.9 million, to $165.3 million for the six months ended July 31, 2022 compared with revenues of $196.2 million for the six months ended July 31, 2021 as the construction activities associated with the Guernsey Power Station project have passed peak levels. The reduction in revenues between the periods was partially offset by an increase in the revenues of APC at several projects including the Kilroot Power Station, the ESB FlexGen peaker plants and the Equinix data center project. The revenues of this business segment represented approximately 75.7% of consolidated revenues for the six months ended July 31, 2022 and 75.6% of consolidated revenues for the six-month period ended July 31, 2021.

The primary drivers for the revenues of this segment for the six months ended July 31, 2021 were the revenues associated with the construction of the Guernsey Power Station and the Maple Hill solar energy facility.

Industrial Fabrication and Field Services

The revenues of our industrial fabrication and field services segment decreased by $11.3 million, or 19.9%, to $45.5 million for the six months ended July 31, 2022 compared to revenues of $56.8 million for the six months ended July 31, 2021 as the amount of pipe and vessel fabrication and field services declined. For the six months ended July 31, 2022 and 2021, the revenues of this segment represented 20.8% and 21.9% of consolidated revenues for the corresponding periods.

Telecommunications Infrastructure Services

The revenue results of this business segment were $7.6 million for the six-month period ended July 31, 2022, an increase of $1.2 million, or 19.3%, from the amount of revenues earned during the six months ended July 31, 2021. The improvement in revenues between the quarters related to increased project activities for outside-premises customers, and new revenues provided by the customers of Lee Telecom, Inc., a company acquired by SMC in December 2021.

Cost of Revenues

With the decrease in consolidated revenues for the six months ended July 31, 2022 compared with last year’s six-month period ended July 31, 2021, the consolidated cost of revenues also decreased between the periods. These costs were $174.3 million and $208.0 million for the six months ended July 31, 2022 and 2021, respectively, representing a decrease of approximately 16.2%.

For the six-month period ended July 31, 2022, we reported a consolidated gross profit of approximately $44.1 million which represented a gross profit percentage of approximately 20.2% of corresponding consolidated revenues. The gross profit percentages of corresponding revenues for the power industry services, industrial services and the telecommunications infrastructure segments were 21.2%, 16.0% and 23.9%, respectively, for the six months ended July 31, 2022.

Our consolidated gross profit reported for the six-month period ended July 31, 2021 was $51.4 million, which represented a gross profit percentage of approximately 19.8% of corresponding consolidated revenues. The gross profit percentages of corresponding revenues for the power industry services, industrial services and the telecommunications infrastructure segments were 19.9%, 19.4% and 21.4%, respectively, for the six-month period ended July 31, 2021.

Selling, General and Administrative Expenses

These costs were $21.6 million and $20.2 million for the six months ended July 31, 2022 and 2021, respectively, representing an increase of $1.3 million between the periods, or 6.6%.

Other Income (Expense), Net

We reported other income, net, in the amount of $1.1 million for the six months ended July 31, 2022 which included primarily our share of earnings associated with our solar fund investments. We reported other income, net, in the amount of $0.5 million for the six months ended July 31, 2021.

Income Taxes

We incurred income tax expense for the six months ended July 31, 2022 in the amount of approximately $12.0 million, including the aforementioned unfavorable adjustment in the amount of $6.2 million related to the settlement of research and development claims with the IRS. Excluding the effect of this adjustment, our effective income tax rate for the six-months ended July 31, 2022 was 24.4%. This estimated tax rate differs from the statutory federal tax rate of 21% due primarily to the estimated unfavorable effects of state income taxes and permanent differences for the year, including certain nondeductible executive compensation and GILTI.

For the six months ended July 31, 2021, we reported income tax expense in the amount of approximately $8.0 million, which represented an actual effective income tax rate of 25.2% for the six-month period. The actual rate for the period reflected unfavorable adjustments to income tax expense including the write-off of certain deferred tax assets related to stock compensation and the estimated unfavorable effects of state income taxes and permanent differences, including certain nondeductible executive compensation and GILTI, offset partially by the favorable adjustment to deferred taxes related to our solar energy projects investments.

Liquidity and Capital Resources as of July 31, 2022

At July 31 and January 31, 2022, our balances of cash and cash equivalents were $143.3 million and $350.5 million, respectively, which represented a decrease of $207.2 million. During the six months between these dates, our working capital decreased by $48.1 million to $236.2 million as of July 31, 2022 from $284.3 million as of January 31, 2022.

The net amount of cash used in operating activities for the six months ended July 31, 2022 was $56.8 million. Our net income for the six months ended July 31, 2022, adjusted favorably by the net amount of non-cash income and expense items, represented a source of cash in the total amount of $15.7 million. However, reductions in the balance of contract liabilities and the combined level of accounts payable and accrued expenses in the amounts of $63.9 million and $16.1 million, respectively, represented uses of cash. Both of these reductions related primarily to the decline in the construction activity of the Guernsey Power Station project, partially offset by an increase in contract liabilities at several APC projects. Additionally, the increase in contract assets in the amount of $3.8 million represented a use of cash during the period. The decreases in the amounts of accounts receivable and other assets in the amounts of $2.1 million and $9.3 million, represented sources of cash during the period.

During the six months ended July 31, 2022, we also used cash to increase the level of our short-term investments, which consist entirely of CDs issued by the Bank, by $85.0 million. We also used $60.3 million cash in financing activities during the six months ended July 31, 2022, including $53.2 million used to repurchase shares of our common stock pursuant to our Share Repurchase Plan, and $7.2 million used for the payment of regular cash dividends. As of July 31, 2022, there were no restrictions with respect to inter-company payments between GPS, TRC, APC, SMC and the holding company. However, certain loans made by Argan to APC have been determined to be uncollectible.

During the six months ended July 31, 2021, our balance of cash and cash equivalents increased by a net amount of $84.7 million. The net amount of cash provided by operating activities for the six months ended July 31, 2021 was $47.2 million. Our net income for the period, adjusted favorably by the net amount of non-cash income and expense items, represented a source of cash in the total amount of $30.6 million. The sources of cash from operations also included the temporary increase in the balance of contract liabilities, primarily associated with projects at GPS, APC and TRC in the amount of $41.7 million. An increase in the amount of accounts receivable and a reduction in the combined level of accounts payable and accrued expenses during the period ended July 31, 2021, in the respective amounts of $14.4 million and $8.8 million, represented uses of cash for the period. The amount of other assets increased by $3.2 million during the six months ended July 31, 2021, which also represented a use of cash for the period.

Other primary sources of cash for the six months ended July 31, 2021 were the net maturities of certificates of deposit and the proceeds associated with the exercise of stock options in the amounts of $50.0 million and $1.0 million, respectively. Non-operating activities also used cash during the six months ended July 31, 2021, including the payment of a regular cash dividends in the amount of $7.9 million, investment payments made to a solar energy investment fund in the amount of $4.1 million and capital expenditures in the amount of $1.0 million.

At July 31, 2022, a portion of our balance of cash and cash equivalents was invested in a money market fund with most of its 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 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 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 July 31, 2022, we had no outstanding borrowings, however, the Bank has issued letters of credit in the total outstanding amount of $15.1 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 again 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 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 July 31, 2022 and January 31, 2022, we were compliant with the 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 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 provided 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 July 31, 2022, the value of the Company’s unsatisfied bonded performance obligations, covering all of its subsidiaries, was approximately $139.6 million. In addition, as of July 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 over the next two years.

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. A liability was established for the estimated loss related to this guarantee during Fiscal 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 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 July 31, 2022 are not estimable.

Returns on money market instruments and certificates of deposit were limited for some time due to market conditions. With the desire to increase the amount of return on its available cash, the Company invested approximately $6.3 million in limited liability companies that makes equity investments in solar energy projects that are eligible to receive energy tax credits. 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.

Earnings before Interest, Taxes, Depreciation and Amortization (“EBITDA”)

The tables following immediately below present the determinations of EBITDA for the three and six months ended July 31, 2022 and 2021, respectively (amounts in thousands).


	Three Months Ended
	July 31,
	2022		2021
Net income, as reported	$	4,222	$	12,870
Income tax expense		9,686		4,191
Depreciation		747		859
Amortization of purchased intangible assets		233		225
EBITDA	$	14,888	$	18,145


	Six Months Ended
	July 31,
	2022		2021
Net income, as reported	$	11,707	$	23,636
Income tax expense		11,959		7,959
Depreciation		1,556		1,741
Amortization of purchased intangible assets		399		453
EBITDA	$	25,621	$	33,789

We believe that EBITDA is a meaningful presentation that enables us to assess and compare our operating 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 U.S. 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.

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 do periodically review these critical accounting policies and estimates with the audit committee of our board of directors.

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; 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 months ended July 31, 2022, there have been no material changes in the way we apply the critical accounting policies described therein.

Recently Issued Accounting Pronouncements

There are no recently issued accounting pronouncements that have not yet been adopted that we consider material to our consolidated financial statements.

ITEM 3. 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 July 31, 2022, we had no outstanding borrowings under our financing arrangements with the Bank (see Note 6 to the accompanying condensed 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 the three months ended July 31, 2022 and 2021, we did not enter into derivative financial instruments for trading, speculation or other purposes that would expose us to market risk.

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 a money market fund (see Note 3 of the accompanying condensed consolidated financial statements). As of July 31, 2022, the weighted average number of days until maturity for the short-term investments and money market fund is 304 days. The weighted average annual interest rate of our certificates of deposit of $175.0 million, which are classified as short-term investments, and the money market fund balance of $54.6 million was 1.17%. To illustrate the potential impact of changes in the overall interest rate associated with our investable cash balance at July 31, 2022 on our annual results of operations, we present the following hypothetical analysis. It assumes that our condensed consolidated balance sheet as of July 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 1.17% at July 31, 2022, the largest decrease in the interest rates presented below is 117 basis points (dollars in thousands).


	Increase (Decrease) in		Increase (Decrease) in		Net Increase (Decrease) in
Basis Point Change	Interest Income		Interest Expense		Income (Pre-Tax)
Up 300 basis points	$	3,681	$	—	$	3,681
Up 200 basis points		2,454		—		2,454
Up 100 basis points		1,227		—		1,227
Down 100 basis points		(1,227)		—		(1,227)
Down 117 basis points		(1,337)		—		(1,337)

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). For example, the amounts of cash, revenues and backlog reported for APC in our condensed consolidated financial statements have declined through the six months ended July 31, 2022 as the Euro has depreciated significantly versus the U.S. dollar. The effects of translation are recognized in accumulated other comprehensive 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 condensed consolidated statement of earnings.

In the “Risk Factors” section of our Annual Report, we 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.

Our operations have been challenged by the well-publicized global supply chain disruptions. While 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 4. CONTROLS AND PROCEDURES

Evaluation of disclosure controls and procedures. Our management, with the participation of our chief executive officer and chief financial officer, evaluated the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934 (the “Exchange Act”)) as of July 31, 2022. Management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving their objectives, and management necessarily applies its judgment in evaluating the cost-benefit relationship of possible controls and procedures. Based on the evaluation of our disclosure controls and procedures as of July 31, 2022, our chief executive officer and chief financial officer concluded that, as of such date, our disclosure controls and procedures 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 the Company and its consolidated subsidiaries is made known to management, including the chief executive officer and chief financial officer, to allow timely decisions regarding required disclosure in the reports.

Changes in internal controls over financial reporting. There have been no significant changes in our internal control over financial reporting (as defined in Rules 13a-15 and 15d-15 under the Exchange Act) during the fiscal quarter ended July 31, 2022 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II

ITEM 1. LEGAL PROCEEDINGS

In the normal course of business, we may have 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 condensed consolidated financial statements.

ITEM 1A. RISK FACTORS

There have been no material changes to the risk factors disclosed in our Annual Report.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

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. 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 repurchase transactions 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 Share 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.

Information related to our share repurchases for the three months ended July 31, 2022 follows.


				Total Number of	Value of Shares That May Yet
				Shares Purchased as Part of	Be Purchased under the
	Total Number of	Average Price per		Publicly Announced	Plans or Programs
Period	Shares Repurchased	Share Paid		Plans or Programs	(Dollars in Thousands)
May 1 - 31, 2022	377,482	$	37.09	377,482	$	13,550
June 1 - 30, 2022	197,622	$	37.85	197,622	$	6,069
July 1 - 31, 2022	126,609	$	36.40	126,609	$	1,460
Total	701,713	$	37.18	701,713

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None

ITEM 4. MINE SAFETY DISCLOSURES (not applicable)

ITEM 5. OTHER INFORMATION

On August 18, 2022, the Company filed a Current Report on Form 8-K (the “Current Report”) including the announcement that its Board of Directors (the “Board”) promoted David H. Watson to be the Company’s President and Chief Executive Officer (“CEO”) and appointed him to the Board, effective August 16, 2022. Mr. Watson previously served as the Company’s Senior Vice President, Chief Financial Officer, Treasurer and Corporate Secretary (“CFO”) since October 2015.

Mr. Watson replaces Rainer H. Bosselmann, who retired from the CEO and Chairman of the Board positions but will continue to serve as a member of the Board. Mr. Bosselmann has entered into a Retirement Agreement with the Company, effective August 16, 2022, that allows for payment of $225,000 per annum and benefits for three years. Mr. Bosselmann’s Retirement Agreement was attached to the Current Report as Exhibit 10.1, and is incorporated by reference as Exhibit 10.1 to this Quarterly Report on Form 10-Q.

The Board appointed a current member William F. Leimkuhler as Chairman of the Board, effective August 16, 2022.

The Company also announced that the Board promoted Richard H. Deily to the position of CFO effective August 16, 2022. Mr. Deily was hired by the Company in October 2007 and previously served the Company as its Vice President, Corporate Controller, since January 2015.

The agreements covering the employment arrangements with Mr. Watson and Mr. Deily in their new positions are filed herewith as Exhibits 10.2 and 10.3, respectively, in lieu of our filing them with an amendment to the Current Report.

ITEM 6. EXHIBITS


Exhibit No.		Title
Exhibit 10.1		Retirement Agreement, dated as of August 16, 2022, 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 August 18, 2022.
Exhibit 10.2		Employment Agreement, dated September 8, 2022, by and between Argan, Inc. and David H. Watson.
Exhibit 10.3		Employment Agreement, dated September 8, 2022, by and between Argan, Inc. and Richard H. Deily.
Exhibit 31.1		Certification of Chief Executive Officer, pursuant to Rule 13a-14(c) under the Securities Exchange Act of 1934.
Exhibit 31.2		Certification of Chief Financial Officer, pursuant to Rule 13a-14(c) under the Securities Exchange Act of 1934.
Exhibit 32.1		Certification of Chief Executive Officer, pursuant to 18 U.S.C. Section 1350. *
Exhibit 32.2		Certification of Chief Financial Officer, pursuant to 18 U.S.C. Section 1350. *

Exhibit 101: Exhibit 101.INS		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.
Exhibit 101.SCH		Inline XBRL Taxonomy Extension Schema.
Exhibit 101.CAL		Inline XBRL Taxonomy Extension Calculation Linkbase.
Exhibit 101.LAB		Inline XBRL Taxonomy Label Linkbase.
Exhibit 101.PRE		Inline XBRL Taxonomy Presentation Linkbase.
Exhibit 101.DEF		Inline XBRLTaxonomy Extension Definition Document.
Exhibit 104		Cover Page Interactive Data File – the cover page interactive data file does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

*	The certification is being furnished and shall not be considered filed as part of this report.

SIGNATURES

Pursuant to the requirements 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.


	ARGAN, INC.

September 8, 2022	By:	/s/ David H. Watson
		David H. Watson
		President and Chief Executive Officer

September 8, 2022	By:	/s/ Richard H. Deily
		Richard H. Deily
		Senior Vice President, Chief Financial Officer,
		Treasurer and Corporate Secretary

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Argan (AGX) 10-Q2023 Q2 Quarterly report

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