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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 September 30, 2022
or
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _____ to _____
Commission File Number 001-37988
NexTier Oilfield Solutions Inc.
(Exact Name of Registrant as Specified in its Charter)
Delaware 38-4016639
(State or Other Jurisdiction of
Incorporation or Organization)
(I.R.S. Employer
Identification No.)
3990 Rogerdale Rd. Houston Texas 77042
(Address of Principal Executive Offices) (Zip Code)
(713) 325-6000
(Registrant's Telephone Number, Including Area Code)
Securities registered pursuant to Section 12(b) of the Act:
Title of Each Class Trading Symbol Name of Each Exchange On Which Registered
Common Stock, $0.01, par value NEX New York Stock Exchange
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes      No  
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).    Yes       No  
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large Accelerated Filer
Accelerated Filer
Non-accelerated Filer
Smaller Reporting Company
Emerging Growth Company
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes      No    
As of October 21, 2022, the registrant had 245,529,851 shares of common stock outstanding.
Auditor Name: KPMG LLP Auditor Location: Houston, Texas Auditor Firm ID: 185



TABLE OF CONTENTS
PART I.
FINANCIAL INFORMATION
3
Item 1.
4
5
6
7
9
Item 2.
Item 3.
Item 4.
PART II.
Item 1.
Item 1A.
Item 2.
Item 3.
Item 4.
Item 5.
Item 6.




REFERENCES WITHIN THIS QUARTERLY REPORT
As used in this Quarterly Report on Form 10-Q, unless the context otherwise requires, references to (i) the terms "Company," "NexTier," "we," "us" and "our" refer to NexTier Oilfield Solutions Inc. and its consolidated subsidiaries; (ii) the term "Keane Group" refers to Keane Group Holdings, LLC and its consolidated subsidiaries; (iii) the term "Keane Investor" refers to Keane Investor Holdings LLC; (iv) the term "Cerberus" refers to Cerberus Capital Management, L.P. and its controlled affiliates and investment funds; and (v) the term "Alamo" refers to Alamo Pressure Pumping, LLC and its consolidated subsidiaries. As used in this Quarterly Report on Form 10-Q, capacity in the hydraulic fracturing business refers to the total number of hydraulic horsepower, regardless of whether such hydraulic horsepower is active and deployed, active and not deployed or inactive. While the equipment and amount of hydraulic horsepower required for a customer project varies, we calculate our total number of fleets, as used in this Quarterly Report on Form 10-Q, by dividing our total hydraulic horsepower by approximately 63,000 hydraulic horsepower.

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS AND INFORMATION
This Quarterly Report on Form 10-Q contains forward-looking statements, within the meaning of the Private Securities Litigation Reform Act of 1995, which are subject to risks and uncertainties. All statements other than statements of historical facts contained in this Quarterly Report on Form 10-Q, including statements regarding our future operating results and financial position, business strategy and plans and objectives of management for future operations, are forward-looking statements. Our forward-looking statements are generally accompanied by words such as "may," "will," "should," "expect," "believe," "plan," "anticipate," "could," "intend," "target," "goal," "project," "contemplate," "estimate," "predict," "potential," "outlook," "reflect," "forecast," "future," or "continue," or the negative of these terms or other similar expressions. Any forward-looking statements contained in this Quarterly Report on Form 10-Q speak only as of the date on which we make them and are based upon our historical performance and on current plans, estimates and expectations. Except as required by law, we have no obligation to update any forward-looking statements made in this Quarterly Report on Form 10-Q to reflect events or circumstances after the date of this Quarterly Report on Form 10-Q or to reflect new information or the occurrence of unanticipated events. Forward-looking statements contained in this Quarterly Report on Form 10-Q include, but are not limited to, statements about:
the continued impact of the COVID-19 pandemic (including as a result of the emergence of new variants and strains of the virus, such as Delta and Omicron) and the evolving response thereto by governments, private businesses or others to contain the spread of the virus and its variants or to treat its impact;
changing regional, national or global economic conditions, including rising inflation and supply chain issues;
the ongoing impact of geopolitical conflicts;
our business strategy;
our plans, objectives, expectations and intentions;
the competitive nature of the industry in which we conduct our business, including pricing pressures;
our future operating results;
crude oil and natural gas demand, production growth, and commodity prices;
demand for services in our industry;
the impact of pipeline and storage capacity constraints;
the impact of adverse weather conditions;
the effects of government regulation;
changes in tax laws;
legal proceedings, liability claims and effect of external investigations;
the effect of a loss of, or the financial distress of, one or more customers;
our ability to obtain or renew customer contracts;
the effect of a loss of, or interruption in operations of, one or more key suppliers;
our ability to maintain the right level of commitments under our supply agreements;
the market price and availability of materials or equipment;
the impact of new technology;
our ability to employ a sufficient number of skilled and qualified workers;
our ability to obtain permits, approvals and authorizations from governmental and third parties;
planned acquisitions, divestitures and future capital expenditures;
our ability to maintain secure and effective information technology systems;
3


our ability to maintain an effective system of internal controls over financial reporting;
our ability to service our debt obligations;
financial strategy, liquidity or capital required for our ongoing operations and acquisitions, and our ability to raise additional capital;
the market volatility of our stock;
our ability or intention to pay dividends or to effectuate repurchases of our common stock;
the impact of ownership by Cerberus (through Keane Investor); and
the impact of our corporate governance structure.
We caution you that the foregoing list may not contain all of the forward-looking statements made in this Quarterly Report on Form 10-Q.
You should not rely upon forward-looking statements as predictions of future events. We have based the forward-looking statements contained in this Quarterly Report on Form 10-Q primarily on our current expectations and projections about future events and trends that we believe may affect our business, financial condition, results of operations and prospects. The outcome of the events described in these forward-looking statements is subject to risks, uncertainties and other factors described in the section entitled Part I, "Item 1A. Risk Factors" of our Annual Report on Form 10-K for the year ended December 31, 2021 and in our subsequent filings with the Securities and Exchange Commission (the "SEC"). Moreover, we operate in a very competitive and rapidly changing environment. New risks and uncertainties emerge from time to time, and it is not possible for us to predict all risks and uncertainties that could have an impact on the forward-looking statements contained in this Quarterly Report on Form 10-Q. We cannot assure you that the results, events, circumstances, plans, intentions or expectations reflected in any forward-looking statements will be achieved or occur. Actual results, events or circumstances could differ materially from those described in such forward-looking statements, and you should not place undue reliance on our forward-looking statements. Our forward-looking statements do not reflect the potential impact of any future acquisitions, mergers, dispositions, joint ventures or investments we may make, except as specifically set forth herein. We undertake no obligation to revise or update any forward-looking statements for any reasons, expect as required by law.
This Quarterly Report on Form 10-Q includes market and industry data and certain other statistical information based on third-party sources including independent industry publications, government publications and other published independent sources. Although we believe these third-party sources are reliable as of their respective dates, we have not independently verified the accuracy or completeness of this information. Some data is also based on our own good faith estimates, which are supported by our management's knowledge of and experience in the markets and businesses in which we operate.
While we are not aware of any misstatements regarding any market, industry or similar data presented herein, such data involves risks and uncertainties and is subject to change based on various factors, including those discussed above and in Part I, "Item 1A. Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2021 and in our subsequent filings with the SEC.
PART I
Item 1. Financial Statements
4


NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Condensed Consolidated Balance Sheets
(Amounts in thousands, except par value)
September 30,
2022
December 31,
2021
(Unaudited) (Audited)
Assets
Current assets:
Cash and cash equivalents
$ 250,207  $ 110,695 
Trade and other accounts receivable, net
479,669  301,740 
Inventories, net
60,008  38,094 
Assets held for sale
—  1,555 
Prepaid and other current assets
53,533  55,625 
Total current assets
843,417  507,709 
Operating lease right-of-use assets
17,487  21,767 
Finance lease right-of-use assets
45,262  41,537 
Property and equipment (net of accumulated depreciation of $984,324 and $951,170)
636,951  620,865 
Goodwill
192,780  192,780 
Intangible assets (net of accumulated amortization of $78,920 and $62,678)
53,117  64,961 
Other noncurrent assets
13,310  7,962 
Total assets
$ 1,802,324  $ 1,457,581 
Liabilities and Stockholders' Equity
Current liabilities:
Accounts payable
$ 288,293  $ 190,963 
Accrued expenses
287,980  213,923 
Customer contract liabilities
23,538  23,729 
Current maturities of long-term operating lease liabilities
5,324  7,452 
Current maturities of long-term finance lease liabilities
18,261  11,906 
Current maturities of long-term debt
13,849  13,384 
Other current liabilities
11,277  10,346 
Total current liabilities
648,522  471,703 
Long-term operating lease liabilities, less current maturities
12,823  20,446 
Long-term finance lease liabilities, less current maturities
17,335  26,873 
Long-term debt, net of unamortized deferred financing costs and unamortized debt discount, less current maturities 350,986  361,501 
Other noncurrent liabilities
9,732  30,041 
Total noncurrent liabilities
390,876  438,861 
Total liabilities
1,039,398  910,564 
Stockholders' equity
Common stock, par value $0.01 per share (authorized 500,000 shares, issued and outstanding 245,519 and 242,019 shares, respectively)
2,455  2,420 
Paid-in capital in excess of par value
1,113,380  1,094,020 
Retained deficit
(359,180) (541,164)
Accumulated other comprehensive loss 6,271  (8,259)
Total stockholders' equity
762,926  547,017 
Total liabilities and stockholders' equity
$ 1,802,324  $ 1,457,581 

See accompanying notes to unaudited condensed consolidated financial statements.
5


NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)
(Amounts in thousands, except for per share amounts)
(Unaudited)
Three Months Ended
September 30,
Nine Months Ended
September 30,
2022 2021 2022 2021
Revenue $ 896,010  $ 393,164  $ 2,373,965  $ 913,711 
Operating costs and expenses:
Cost of services(1)
682,683  344,637  1,857,205  831,674 
Depreciation and amortization 56,542  44,861  170,499  131,400 
Selling, general and administrative expenses 37,415  37,453  109,129  74,256 
Merger and integration 27,521  4,752  60,435  4,930 
Gain on disposal of assets (10,471) (1,133) (12,160) (7,742)
Total operating costs and expenses
793,690  430,570  2,185,108  1,034,518 
Operating income (loss) 102,320  (37,406) 188,857  (120,807)
Other income (expense):
Other income, net 11,124  585  17,955  9,113 
Interest expense, net (7,150) (6,701) (21,868) (16,633)
Total other income (expense) 3,974  (6,116) (3,913) (7,520)
Income (loss) before income taxes 106,294  (43,522) 184,944  (128,327)
Income tax expense (1,560) (472) (2,960) (1,950)
Net Income (loss) 104,734  (43,994) 181,984  (130,277)
Other comprehensive income (loss), net of tax:
Foreign currency translation adjustments 1,037  531  1,290  433 
Hedging activities 4,421  (46) 11,598  785 
Total comprehensive income (loss) $ 110,192  $ (43,509) $ 194,872  $ (129,059)
Net income (loss) per share:
Basic net income (loss) per share $ 0.43  $ (0.20) $ 0.75  $ (0.60)
Diluted net income (loss) per share $ 0.42  $ (0.20) $ 0.73  $ (0.60)
Weighted-average shares outstanding: basic 244,686 224,481  243,980 218,499 
Weighted-average shares outstanding: diluted 250,821 224,481  249,864 218,499 
(1) Cost of services during the three and nine months ended September 30, 2022 excludes depreciation and amortization of $52.1 million and $157.3 million, respectively. Cost of services during the three and nine months ended September 30, 2021 excludes depreciation and amortization of $40.5 million and $118.1 million, respectively.
See accompanying notes to unaudited condensed consolidated financial statements.
6


NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Condensed Consolidated Statements of Changes in Stockholders' Equity
(Amounts in thousands)
(Unaudited)

Common stock Paid-in capital in excess of par value Retained deficit Accumulated other comprehensive income (loss) Total
Balance as of December 31, 2021 $ 2,420  $ 1,094,020  $ (541,164) $ (8,259) $ 547,017 
Stock-based compensation 19  7,796  —  —  7,815 
Shares repurchased and retired related to stock-based compensation —  (3,953) —  —  (3,953)
Other comprehensive income —  —  —  6,014  6,014 
Net income —  —  8,792  —  8,792 
Balance as of March 31, 2022 $ 2,439  $ 1,097,863  $ (532,372) $ (2,245) $ 565,685 
Stock-based compensation 7,540  —  —  7,547 
Shares repurchased and retired related to stock-based compensation (4) (397) —  —  (401)
Other comprehensive income —  —  —  2,794  2,794 
Net income —  —  68,458  —  68,458 
Balance as of June 30, 2022 $ 2,442  $ 1,105,006  $ (463,914) $ 549  $ 644,083 
Stock-based compensation 7,111  —  —  7,119 
Shares repurchased and retired related to stock-based compensation —  (2,939) —  —  (2,939)
Equity issued in connection with CIG Acquisition 4,202  —  —  4,207 
Other comprehensive income —  —  —  5,722  5,722 
Net income —  —  104,734  —  104,734 
Balance as of September 30, 2022 $ 2,455  $ 1,113,380  $ (359,180) $ 6,271  $ 762,926 




7


NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Condensed Consolidated Statements of Changes in Stockholders' Equity
(Amounts in thousands)
(Unaudited)
Common stock Paid-in capital in excess of par value Retained deficit Accumulated other comprehensive income (loss) Total
Balance as of December 31, 2020 $ 2,144  $ 989,995  $ (421,741) $ (13,110) $ 557,288 
Stock-based compensation 10  5,193  —  —  5,203 
Shares repurchased and retired related to stock-based compensation (1) (1,009) —  —  (1,010)
Other comprehensive income —  —  —  2,349  2,349 
Net loss —  —  (54,502) —  (54,502)
Balance as of March 31, 2021 $ 2,153  $ 994,179  $ (476,243) $ (10,761) $ 509,328 
Stock-based compensation 4,884  —  —  4,889 
Shares repurchased and retired related to stock repurchase program (1) (435) —  —  (436)
Other comprehensive loss —  —  —  (267) (267)
Net loss —  —  (31,781) —  (31,781)
Balance as of June 30, 2021 $ 2,157  $ 998,628  $ (508,024) $ (11,028) $ 481,733 
Stock-based compensation 7,346  —  —  7,350 
Shares repurchased and retired related to stock repurchase program (1) (419) —  —  (420)
Equity issued in connection with Alamo Acquisition 260  82,063  —  —  82,323 
Other comprehensive loss —  —  —  1,179  1,179 
Net loss —  —  (43,994) —  (43,994)
Balance as of September 30, 2021 $ 2,420  $ 1,087,618  $ (552,018) $ (9,849) $ 528,171 
See accompanying notes to unaudited condensed consolidated financial statements.
8



NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Condensed Consolidated Statements of Cash Flows
(Amounts in thousands)
(Unaudited)
Nine Months Ended
September 30,
2022 2021
Cash flows from operating activities:
Net income (loss) $ 181,984  $ (130,277)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities
Depreciation and amortization 170,499  131,400 
Amortization of deferred financing fees 1,634  1,528 
Gain on disposal of assets (12,160) (7,742)
Unrealized gain on derivative recognized in other comprehensive loss —  785 
(Gain) loss on financial instrument and derivatives, net (6,299) 4,142 
Stock-based compensation 24,862  17,442 
Gain on insurance proceeds recognized in other income (11,044) (10,409)
Changes in operating assets and liabilities:
Increase in trade and other accounts receivable, net (177,955) (92,184)
Increase in inventories (26,523) (9,046)
Decrease (increase) in prepaid and other current assets 27,625  (10,138)
Decrease in other assets 8,945  14,203 
Increase in accounts payable 77,964  59,072 
Increase in accrued expenses 76,600  42,951 
Decrease in customer contract liabilities (192) (3,468)
Decrease in other liabilities (25,619) (27,579)
Net cash provided by (used in) operating activities 310,321  (19,320)
Cash flows from investing activities:
Purchase of property and equipment (136,770) (132,057)
Advances of deposit on equipment (5,884) (543)
Implementation of software (2,986) (2,532)
Proceeds from disposal of assets 36,098  24,470 
Assets and business acquisition (26,694) (95,082)
Payment of consideration liability —  (6,671)
Proceeds from settlement of WSS Notes and make-whole derivative —  34,350 
Proceeds from insurance recoveries 845  22,947 
Net cash used in investing activities (135,391) (155,118)
Cash flows from financing activities:
Proceeds from asset-based revolver and equipment loan —  39,428 
Payments on the term loan facility and asset based revolver (10,977) (2,625)
Payments on finance leases (10,056) (1,146)
Payment of debt issuance costs (110) (251)
Payments for financing liabilities (5,799) — 
Payments for contingent consideration (2,473) — 
Shares repurchased and retired related to stock-based compensation (7,293) (1,866)
Net cash provided (used) in financing activities (36,708) 33,540 
Non-cash effect of foreign translation adjustments 1,290  433 
Net increase (decrease) in cash, cash equivalents 139,512  (140,465)
Cash and cash equivalents, beginning 110,695  275,990 
Cash and cash equivalents, ending $ 250,207  $ 135,525 
9



NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Condensed Consolidated Statements of Cash Flows
(Amounts in thousands)
(Unaudited)
Supplemental disclosure of cash flow information:
Cash paid during the period for:
Interest expense, net $ 19,434  $ 16,469 
Income taxes 1,260  — 
Non-cash investing and financing activities:
Change in accrued capital expenditures $ (19,404) $ (19,763)
Non-cash additions to finance right-of-use assets 7,115  35,813 
Non-cash additions to finance lease liabilities, including current maturities (6,874) (35,813)
Non-cash additions to operating right-of-use assets 5,100  3,352 
Non-cash additions to operating lease liabilities, including current maturities $ (5,016) $ (512)
500,000 shares of NexTier common stock issued for asset acquisition
$ (4,207) $ — 
26,000,000 shares of NexTier common stock issued in exchange for Alamo ownership
—  (82,323)
Total contingent consideration —  (45,944)
Non contingent consideration $ —  $ (7,370)

See accompanying notes to unaudited condensed consolidated financial statements.

10


NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements

(1)    Basis of Presentation and Nature of Operations
The accompanying unaudited condensed consolidated financial statements were prepared using United States Generally Accepted Accounting Principles ("GAAP") and the instructions to Form 10-Q and Regulation S-X. Accordingly, these financial statements do not include all information or notes required by GAAP for annual financial statements and should be read together with the Company's Annual Report on Form 10-K for the year ended December 31, 2021, filed with the SEC on February 23, 2022.
The Company’s accounting policies are in accordance with GAAP. The preparation of financial statements in conformity with these accounting principles requires the Company to make estimates and assumptions that affect (i) the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and (ii) the reported amounts of revenue and expenses during the reporting period. Ultimate results could differ from the Company’s estimates. Significant items subject to such estimates and assumptions include the useful lives of property and equipment and intangible assets; inventory reserves; acquisition accounting; contingent liabilities; and the valuation of property and equipment, intangible assets, equity issued as consideration in an acquisition, income taxes, stock-based incentive plan awards and derivatives.
Management believes the unaudited condensed consolidated financial statements included herein contain all adjustments necessary to present fairly the Company's financial position as of September 30, 2022 and the results of its operations and cash flows for the three and nine months ended September 30, 2022 and 2021. Such adjustments are of a normal recurring nature. All intercompany transactions and balances have been eliminated.
On August 31, 2021, the Company completed its acquisition (the “Alamo Acquisition”) of Alamo. Merger and integration related costs were recognized separately from the acquisition of assets and assumptions of liabilities in the Alamo Acquisition. Merger costs consist of legal and professional fees and pre-merger notification fees. Integration costs consist of expenses incurred to integrate Alamo’s operations, aligning accounting processes and procedures, integrating its enterprise resource planning system with those of the Company, and any earnout payments. All of these costs are recorded within merger and integration costs on the Company’s Condensed Consolidated Statements of Operations and Comprehensive Income (Loss). For additional detailed information regarding the Alamo Acquisition, see Note (3) Acquisitions.
The consolidated financial statements prior to August 31, 2021 reflect only the historical results of the Company prior to the completion of the Alamo Acquisition. The financial statements have been prepared using the acquisition method of accounting under existing GAAP, which requires that one of the two companies in the Alamo Acquisition be designated as the acquirer for accounting purposes. The Company and Alamo determined that the Company was the accounting acquirer. Accordingly, consideration given by the Company to complete the Alamo Acquisition was allocated to the underlying tangible and intangible assets and liabilities acquired based on their estimated fair values as of the date of completion of the Alamo Acquisition, with any excess purchase price allocated to goodwill.
11


NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
(2)    Summary of Significant Accounting Policies
(a) Business Combinations and Asset Acquisitions
Business combinations are accounted for using the acquisition method of accounting in accordance with the Accounting Standards Codification (“ASC”) 805, “Business Combinations”, as amended by Accounting Standards Update (“ASU”) 2017-01, “Business Combinations (Topic 805), Clarifying the Definition of a Business.” The purchase price is allocated to the assets acquired and liabilities assumed based on their estimated fair values. Fair values of the acquired assets and liabilities are measured in accordance with the guidance of ASC 820, using discounted cash flows and other applicable valuation techniques. Every reporting period, the Company reassess the value of any contingent consideration assumed as part of a business acquisition. Any acquisition-related costs incurred by the Company are expensed as incurred. Any excess purchase price over the fair value of the net identifiable assets acquired is recorded as goodwill if the definition of a business is met. Operating results of an acquired business are included in the Company’s results of operations from the date of acquisition.
Asset acquisitions are measured based on their cost to the Company, including transaction costs. Asset acquisition costs, or the consideration transferred by the Company, are assumed to be equal to the fair value of the net assets acquired. If the consideration transferred is cash, measurement is based on the amount of cash the Company paid to the seller, as well as transaction costs incurred. Consideration given in the form of non-monetary assets, liabilities incurred or equity interests issued is measured based on either the cost to the Company or the fair value of the assets or net assets acquired, whichever is more clearly evident. The cost of an asset acquisition is allocated to the assets acquired based on their estimated relative fair values. Goodwill is not recognized in an asset acquisition.
(b) Revenue Recognition
The majority of the Company’s performance obligations are satisfied over time. The Company has determined this best represents the transfer of value from its services to the customer as performance by the Company helps to enhance a customer controlled asset (e.g., unplugging a well, enabling a well to produce oil or natural gas). Measurement of the satisfaction of the performance obligation is measured using the output method, which is typically evidenced by a field ticket. A field ticket includes items such as services performed, consumables used, and man hours incurred to complete the job for the customer. Each field ticket is used to invoice customers. Payment terms for invoices issued are in accordance with a master services agreement with each customer, which typically require payment within 30 to 60 days of the invoice issuance.
A portion of the Company’s contracts contain variable consideration. However, this variable consideration is typically unknown at the time of contract inception and is not known until the job is complete, at which time the variability is resolved. Examples of variable consideration include the number of hours that will be incurred and the amount of consumables (such as chemicals and proppants) that will be used to complete a job.
Remaining Performance Obligations
The Company invoices its customers for the services provided at contractual rates multiplied by the applicable unit of measurement, including volume of consumables used and hours incurred. In accordance with ASC 606, the Company has elected the “Right to Invoice” practical expedient for all contracts, which allows the Company to invoice its customers in an amount that corresponds directly with the value to the customer of the Company’s performance completed to date. With this election, the Company is not required to disclose information about the variable consideration related to its remaining performance obligations. The Company has also elected the practical expedient to expense immediately mobilization costs, as the amortization period would always be less than one year. The Company has identified one contract with a remaining term of more than one year, for which the Company had approximately $21.3 million of unsatisfied performance obligations as of September 30, 2022, which will be recognized as services are performed over the remaining contractual terms.
The Company’s obligations for refunds as well as the warranties and related obligations stated in its contracts with its customers are standard to the industry and are related to the correction of any defectiveness in the execution of its performance obligations.
Contract Balances
In line with industry practice, the Company bills its customers for its services in arrears, typically when the stage or well is completed or at month-end. The majority of the Company’s jobs are completed in less than 30 days. Furthermore, it is currently not standard practice for the Company to execute contracts with prepayment features. As of September 30, 2022, the majority of the
12


NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
Company’s customer contract liability balance is related to the post close service agreement as a result of the Alamo Acquisition. Payment terms after invoicing are typically 30 to 60 days.
The Company does not have any significant contract costs to obtain or fulfill contracts with customers; as such, no amounts are recognized on the consolidated balance sheet. Taxes collected from customers and remitted to governmental authorities are accounted for on a net basis and, therefore, are excluded from revenues in the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) and net cash provided by operating activities in the Condensed Consolidated Statements of Cash Flows.
The following is a description of the Company’s core service lines separated by reportable segments from which the Company generates its revenue. For additional detailed information regarding reportable segments, see Note (14) Business Segments.
Revenue from the Company’s (i) Completion Services and (ii) Well Construction and Intervention (“WC&I”) segments are recognized as follows:
Completion Services
The Company provides hydraulic fracturing, wireline and pumpdown services pursuant to contractual arrangements, such as term contracts and pricing agreements. In late 2020, the Company began evolving its completion service offerings to develop an integrated natural gas treatment and delivery solution. In 2021, the Company launched its new Power Solutions business, which focuses on gas sourcing, compression, transport, decompression, treatment and related services for its fracturing operations. Revenue from these services are earned as services are rendered, which is generally on a per stage or fixed monthly rate. All revenue is recognized when a contract with a customer exists, the performance obligations under the contract have been satisfied over time, the amount to which the Company has the right to invoice has been determined and collectability of amounts subject to invoice is probable. Contract fulfillment costs, such as mobilization costs and shipping and handling costs, are expensed as incurred and are recorded in cost of services in the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss). To the extent fulfillment costs are considered separate performance obligations that are billable to the customer, the amounts billed are recorded as revenue in the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss).
Once a stage has been completed or products and services have been provided, a field ticket is created that includes charges for the services performed and the chemicals, proppant and compressed natural gas consumed during the course of service. The field ticket may also include charges for the mobilization of the equipment to the location, any additional equipment used on the job and other miscellaneous items. The field ticket represents the amounts to which the Company has the right to invoice and to recognize as revenue.
WC&I
The Company provides cementing services pursuant to contractual arrangements, such as term contracts, or on a spot market basis. Revenue is recognized upon the completion of each performance obligation, which for cementing services, represents the portion of the well cemented: surface casing, intermediate casing or production liner. The performance obligations are satisfied over time. Jobs for these services are typically short term in nature, with most jobs completed in a day. Once the well has been cemented, a field ticket is created that includes charges for the services performed and the consumables used during the course of service. The field ticket represents the amounts to which the Company has the right to invoice and to recognize as revenue.
On August 1, 2022, the Company sold its coiled tubing assets to Gladiator Energy LLC ("Gladiator") for a cash purchase price of $21.6 million, which resulted in a gain on sale of assets of $11.6 million. Prior to the sale, the Company provided a range of coiled tubing services used for fracturing plug drill-out during completion operations and for well workover and maintenance, primarily on a spot market basis. Jobs for these services were typically short-term in nature, lasting anywhere from a few hours to multiple days. Revenue was recognized upon completion of each day’s work based upon a completed field ticket. The field ticket included charges for the services performed and the consumables used during the course of service. The field ticket may have also included charges for the mobilization and set-up of equipment, the personnel on the job, any additional equipment used on the job, and other miscellaneous consumables. The Company typically would charge the customer for the services performed and resources provided on an hourly basis at agreed-upon spot market rates or pursuant to pricing agreements.
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
Disaggregation of Revenue
Revenue activities during the three and nine months ended September 30, 2022 and 2021 were as follows:
Three Months Ended September 30, 2022 Nine Months Ended September 30, 2022
(Thousands of Dollars) (Thousands of Dollars)
Completion Services WC&I Total Completion Services WC&I Total
Geography
Northeast $ 110,246  $ 8,505  $ 118,751  $ 310,123  $ 20,391  $ 330,514 
Central 165,505  —  165,505  438,596  —  438,596 
West Texas 514,316  28,250  542,566  1,391,379  88,353  1,479,732 
West 64,961  1,504  66,465  113,984  3,801  117,785 
International 2,723  —  2,723  7,338  —  7,338 
$ 857,751  $ 38,259  $ 896,010  $ 2,261,420  $ 112,545  $ 2,373,965 

Three Months Ended September 30, 2021 Nine Months Ended September 30, 2021
(Thousands of Dollars) (Thousands of Dollars)
Completion Services WC&I Total Completion Services WC&I Total
Geography
Northeast $ 64,140  $ 4,859  $ 68,999  $ 177,448  $ 16,978  $ 194,426 
Central 72,861  —  72,861  162,410  —  162,410 
West Texas 168,176  20,902  189,078  407,643  49,511  457,154 
West 50,511  1,336  51,847  60,794  3,335  64,129 
International 10,379  —  10,379  35,592  —  35,592 
$ 366,067  $ 27,097  $ 393,164  $ 843,887  $ 69,824  $ 913,711 
(c) Long-Lived Assets with Definite Lives
Property and equipment, inclusive of equipment under finance lease, are generally stated at cost.
Depreciation on property and equipment is calculated using the straight-line method over the estimated useful lives of the assets, which range from 13 months to 40 years. Management determines the estimate of the useful lives and salvage values of property and equipment on expected utilization, technological change and effectiveness of its maintenance programs. Depreciation methods, useful lives and residual values are reviewed annually or as needed based on activities related to specific assets. When components of an item of property and equipment are identifiable and have different useful lives, they are accounted for separately as major components of property and equipment.
Gains and losses on disposal of property and equipment are determined by comparing the proceeds from disposal with the carrying amount of property and equipment and are recognized net within operating costs and expenses in the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss).

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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
Major classifications of property and equipment and their respective useful lives are as follows:
Land
Indefinite life
Building and leasehold improvements
13 months – 40 years
Machinery and equipment
13 months – 25 years
Office furniture, fixtures and equipment
3 years – 5 years
Leasehold improvements are assigned a useful life equal to the term of the related lease, or its expected period of use. Depreciation methods, useful lives and residual values are reviewed annually.
During the third quarter of 2022, one of the Company’s hydraulic frac fleets operating in the Permian Basin was involved in an accidental fire, which resulted in a loss of fracturing equipment; no parties were injured as a result of this incident. As of September 30, 2022, the Company recognized a $15.3 million receivable related to insurance proceeds in other current assets for replacement costs of the damaged equipment, which offsets the $4.3 million loss recognized on the damaged equipment and costs to remove the equipment. The resulting gain of $11.0 million was recognized in other income (expense), net in the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss).
Amortization on definite-lived intangible assets is calculated using the straight-line method over the estimated useful lives of the assets, which range from 2 to 15 years. The majority of the Company's definite lived intangible assets include customer contracts and technology.
Property and equipment and definite-lived intangible assets (“Long-lived Assets”) are evaluated annually or upon the occurrence of events or changes in circumstances, referred to as triggering events, that may indicate the carrying value of a Long-lived Asset may not be recoverable. An impairment loss is recorded in the period in which it is determined that the carrying amount of a Long-lived Asset is not recoverable. The determination of recoverability is made based upon the estimated undiscounted future net cash flows of assets grouped at the lowest level for which there are identifiable cash flows independent of the cash flows of other groups of assets with such cash flows to be realized over the estimated remaining useful life of the primary asset within the asset group. The Company determined the lowest level of identifiable cash flows that are independent of other asset groups to be primarily at the service line level. Following the sale of the Company's coiled tubing assets to Gladiator, the Company's asset groups consist of fracturing services, wireline and cementing. Estimates of undiscounted future net cash flows of assets groups are projected based on estimates of projected revenue growth, unit count, utilization, pricing, gross profit rates, SG&A rates, working capital fluctuations and capital expenditures. Forecasted cash flows take into account known market conditions as of the assessment date, and management’s anticipated business outlook. A terminal period is used to reflect an estimate of stable, perpetual growth. If the estimated undiscounted future net cash flows for a given asset group is less than the carrying amount of the asset groups, an impairment loss is determined by comparing the estimated fair value with the carrying value of the related asset groups. The impairment loss is then allocated across the asset group's major classifications.
The Company did not recognize any impairment charges related to the Company’s long-lived assets for the three and nine months ended September 30, 2022 or 2021.
(d) Leases
In accordance with ASU 2016-02, the Company considers any contract that conveys the right to control the use of identified property, plant or equipment for a period of time in exchange for consideration to be a lease. The Company determines whether the contract into which it has entered is a lease at the lease commencement date. Rental arrangements with term lengths of one month or less are expensed as incurred, but not recognized as qualifying leases.
For lessees, leases can be classified as finance leases or operating leases, while for lessors, leases can be classified as sales-type leases, direct financing leases or operating leases. As lessee, all leases, with the exception of short-term leases, are capitalized on the balance sheet by recording a lease liability, which represents the Company's obligation to make lease payments arising from the lease and a right-of-use ("ROU") asset, which represents the Company's right to use the underlying asset being leased.
For leases in which the Company is the lessee, the Company uses a collateralized incremental borrowing rate to calculate the lease liability, as for most leases, the implicit rate in the lease is unknown. The collateralized incremental borrowing rate is based on a yield curve over various term lengths that approximates the borrowing rate the Company would receive if it collateralized its lease arrangements with all of its assets. For leases in which the Company is the lessor, the Company uses the rate implicit in the lease.
15


NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
For finance leases, the Company amortizes the ROU asset on a straight-line basis over the earlier of the useful life of the ROU asset or the end of the lease term and records this amortization in depreciation and amortization expense on the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss). For finance leases where the Company has determined it is reasonably certain to exercise a purchase option to acquire the underlying asset, the lessee amortizes the ROU asset to the later of the end of the underlying asset’s useful life or lease term and records this amortization in depreciation and amortization expense on the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss). The Company adjusts the lease liability to reflect lease payments made during the period and interest incurred on the lease liability using the effective interest method. The incurred interest expense is recorded in interest expense on the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss). For operating leases, the Company recognizes one single lease cost, comprised of the lease payments and amortization of any associated initial direct costs, within rent expense on the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss). Variable lease costs not included in the determination of the lease liability at the commencement of a lease are recognized in the period when the specified target that triggers the variable lease payments becomes probable.

In accordance with ASC 842, the Company has made the following elections for its lease accounting:
all short-term leases with term lengths of 12 months or less will not be capitalized; the underlying class of assets to which the Company has applied this expedient is primarily its apartment leases;
for non-revenue contracts containing both lease and non-lease components, both components will be combined and accounted for as one lease component and accounted for under ASC 842; and
for revenue contracts containing both lease and non-lease components, both components will be combined and accounted for as one component and accounted for under ASC 606.
(e) Derivative Instruments and Hedging Activities
The Company utilizes interest rate derivatives to manage interest rate risk associated with its floating-rate borrowings. The Company recognizes all derivative instruments as either assets or liabilities on the consolidated balance sheets at their respective fair values. For derivatives designated in hedging relationships, changes in the fair value are either offset through earnings against the change in fair value of the hedged item attributable to the risk being hedged or recognized in accumulated other comprehensive income (loss) until the hedged item affects earnings.

The Company only enters into derivative contracts that it intends to designate as hedges for the variability of cash flows to be received or paid related to a recognized asset or liability (i.e. cash flow hedge). For all hedging relationships, the Company formally documents the hedging relationship and its risk-management objective and strategy for undertaking the hedge, the hedging instrument, the hedged transaction, the nature of the risk being hedged and how the hedging instrument’s effectiveness in offsetting the hedged risk will be assessed prospectively and retrospectively. The Company also formally assesses, both at the inception of the hedging relationship and on an ongoing basis, whether the derivatives that are used in hedging relationships are highly effective in offsetting changes in cash flows of hedged transactions. For derivative instruments that are designated and qualify as part of a cash flow hedging relationship, the gain or loss on the derivative is reported as a component of other comprehensive income (loss) and reclassified into earnings in the same period or periods during which the hedged transaction affects earnings.
The Company discontinues hedge accounting prospectively, when it determines that the derivative is no longer highly effective in offsetting cash flows attributable to the hedged risk, the derivative expires or is sold, terminated, or exercised, the originally forecasted transaction is no longer probable of occurring or if management decides to remove the designation of the cash flow hedge. The net derivative instrument gain or loss related to a discontinued cash flow hedge shall continue to be reported in accumulated other comprehensive income (loss) and reclassified into earnings in the same period or periods during which the originally hedged transaction affects earnings, unless it is probable that the forecasted transaction will not occur by the end of the originally specified time period. When it is probable that the originally forecasted transaction will not occur by the end of the originally specified time period, the Company recognizes immediately, in earnings, any gains and losses related to the hedging relationship that were recognized in accumulated other comprehensive income (loss). In all situations in which hedge accounting is discontinued and the derivative remains outstanding, the Company continues to carry the derivative at its fair value on the consolidated balance sheets and recognizes any subsequent changes in the derivative’s fair value in earnings.
In addition, we evaluate the terms of our operating agreements and other contracts, if any, to determine whether they contain embedded components that are required to be bifurcated and accounted for separately as derivative financial instruments.
For additional detailed information regarding derivatives, see Note (7) Derivatives.
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
(f) Stock-based compensation
The Company recognizes compensation expense for restricted stock awards ("RSAs"), restricted stock units to be settled in common stock (“RSUs”), performance-based RSU awards (“PSUs”), non-qualified stock options (“stock options”), and performance unit awards (“PUs”) based on the fair value of the awards at the date of grant. The fair value of RSAs and RSUs is determined based on the number of shares or RSUs granted and the closing price of the Company’s common stock on the date of grant. The fair value of stock options is determined by applying the Black-Scholes model to the grant-date market value of the underlying common shares of the Company. The fair value of PSUs and PUs with market conditions are determined using a Monte Carlo simulation method. The Company has elected to recognize forfeiture credits for these awards as they are incurred, as this method best reflects actual stock-based compensation expense. Compensation expense from time-based RSAs, RSUs, PSUs, PUs, and stock options is amortized on a straight-line basis over the requisite service period, which is generally the vesting period.
The PUs are settled in cash and therefore are recorded as liability-classified awards. The PUs are remeasured at fair value every reporting period and the Company recognizes compensation cost for the changes in fair value pro-rated for the portion of the requisite service period rendered.
Tax deductions on the stock-based compensation awards are not realized until the awards are vested or exercised. The Company recognizes deferred tax assets for stock-based compensation awards that will result in future deductions on its income tax returns, based on the amount of tax deduction for stock-based compensation recognized at the statutory tax rate in the jurisdiction in which the Company will receive a tax deduction. If the tax deduction for a stock-based award is greater than the cumulative GAAP compensation expense for that award upon realization of a tax deduction, an excess tax benefit will be recognized and recorded as a favorable impact on the effective tax rate. If the tax deduction for an award is less than the cumulative GAAP compensation expense for that award upon realization of the tax deduction, a tax shortfall will be recognized and recorded as an unfavorable impact on the effective tax rate. Any excess tax benefits or shortfalls will be recorded as discrete, adjustments in the period in which they occur. The cash flows resulting from any excess tax benefit will be classified as financing cash flows in the Condensed Consolidated Statements of Cash Flows.
The Company provides its employees with the option to settle income tax obligations arising from the vesting of their restricted or deferred stock-based compensation awards by withholding shares equal to such income tax obligations. Shares acquired from employees in connection with the settlement of the employees’ income tax obligations are accounted for as treasury shares that are subsequently retired. RSAs, RSUs, and PSUs are not considered issued and outstanding for purposes of earnings per share calculations until vested.
For additional information, see Note (9) Stock-Based Compensation.
(3) Acquisitions
(a) Alamo Acquisition
On August 31, 2021 (the “Alamo Acquisition Date”), the Company completed the Alamo Acquisition in accordance with the terms of the Purchase Agreement, dated as of August 4, 2021 (the “Purchase Agreement”), by and among the Company, NexTier Completion Solutions Inc., Alamo Frac Holdings, LLC, Alamo and the “owner group” identified therein. The Company acquired 100% of Alamo.
The Alamo Acquisition was completed for cash consideration of $100.0 million, equity consideration of 26 million shares of the Company’s common stock valued at $82.3 million, post-closing services valued at $30.0 million, an estimated $15.9 million of contingent consideration, $7.4 million of non-contingent consideration, and a net working capital settlement of $0.5 million that was finalized in the fourth quarter of 2021 and was paid to the Company in the first quarter of 2022. The contingent consideration includes a Tier II upgrade payment and earnout payments, which are contingent upon the achievement of certain performance targets, as described in the Purchase Agreement.
The Company accounted for the Alamo Acquisition using the acquisition method of accounting. The aggregate purchase price noted above was allocated to the assets acquired and liabilities assumed based upon their estimated fair values at the date of the acquisition. The measurements of some assets acquired and liabilities assumed, such as intangible assets and the earnout were based on inputs that are not observable in the market and thus represent Level 3 inputs. The fair value of acquired property and equipment were based on both available market data and a cost approach.
17


NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
The following table summarizes the fair value of the consideration transferred in the Alamo Acquisition and the allocation of the purchase price to the fair values of the assets acquired and liabilities assumed at the Alamo Acquisition Date:
Total Purchase Consideration
(Thousands of Dollars)
Preliminary Purchase Price Allocation Adjustments Final Purchase Price Allocation
Cash consideration(1)
$ 100,000  $ —  $ 100,000 
Equity consideration 82,323  —  82,323 
Post close services 30,000  —  30,000 
Contingent consideration 15,944  —  15,944 
Non contingent consideration 7,370  —  7,370 
Net working capital adjustment —  (482) (482)
Total purchase consideration $ 235,637  $ (482) $ 235,155 
Cash
$ 7,419  $ —  $ 7,419 
Trade and accounts receivable
50,619  —  50,619 
Inventories
1,726  —  1,726 
Prepaid and other current assets
19,654  —  19,654 
 Assets held for sale 3,282  —  3,282 
Property and equipment
114,705  (816) 113,889 
Intangible assets
27,113  —  27,113 
Finance lease right-of-use assets 35,813  (468) 35,345 
Other noncurrent assets
1,676  —  1,676 
Total identifiable assets acquired
262,007  (1,284) 260,723 
Accounts payable
39,101  —  39,101 
Accrued expenses
38,000  —  38,000 
Current maturities of long-term finance lease liabilities 10,125  —  10,125 
Long-term finance lease liabilities 25,688  (468) 25,220 
Non-current liabilities
971  —  971 
Total liabilities assumed
113,885  (468) 113,417 
Goodwill
87,515  334  87,849 
Total purchase consideration $ 235,637  $ (482) $ 235,155 
(1) Includes $32.3 million of payments for indebtedness on behalf of Alamo.
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
The following combined pro forma information assumes the Alamo Acquisition occurred on January 1, 2020. The pro forma information presented below is for illustrative purposes only and does not reflect future events that occurred after September 30, 2021 or any operating efficiencies or inefficiencies that resulted from the Alamo Acquisition. The information is not necessarily indicative of results that would have been achieved had the Company controlled Alamo during the period presented. Pro forma adjustments related to the elimination of historical interest expense for debt paid off as part of the Alamo Acquisition were $0.4 million and $2.7 million during the three and nine months ended September 30, 2021, respectively.
(unaudited, amounts in Thousands of Dollars)
Three Months Ended September 30, 2021 Nine Months Ended September 30, 2021
Revenue $ 454,113  $ 1,124,136 
Net loss (44,392) (116,291)
Net loss per share (basic) $ (0.18) $ (0.48)
Net loss per share (diluted) $ (0.18) $ (0.48)
(b) Asset Acquisition from Continental Intermodal Group LP
On August 3, 2022 the Company entered into and closed a definitive agreement to purchase substantially all assets (and assume certain lease liabilities) of the sand hauling, wellsite storage and last mile logistics businesses of Continental Intermodal Group LP (“CIG”) and its subsidiaries (the “CIG Acquisition”) from CIG, Continental Intermodal Group – Trucking, LLC (“Trucking”) and CIG Logistics LLC (together with Trucking and CIG, “CIG Sellers”).
The CIG Acquisition was completed for a purchase price of $31.3 million. At the time of close, the Company paid a total of $32.1 million, which included: (i) approximately $27.9 million in cash paid at closing to the CIG Sellers plus (ii) 500,000 shares of common stock. The $32.1 million transferred to CIG at the time of close included a deposit of $0.8 million for a transition services agreement for costs of services to be provided during the transition period. Accordingly, the purchase price of $31.3 million does not include the deposit of $0.8 million. The Company accounted for this acquisition as an asset acquisition pursuant to ASC 805. The purchase price of the acquisition was allocated amongst the acquired assets as the fair value of the acquired machinery and equipment assets represented substantially all of the fair value of the gross assets acquired. Additionally, the Company established a right of use asset and an operating lease liability of $0.9 million for the assumed lease liability.
(4)    Inventories, net
Inventories, net, consisted of the following as of September 30, 2022 and December 31, 2021:
(Thousands of Dollars)
September 30,
2022
December 31,
2021
Sand, including freight $ 18,183  $ 9,674 
Chemicals and consumables 7,128  4,204 
Materials and supplies 34,697  24,216 
Total inventory, net $ 60,008  $ 38,094 
Inventories are reported net of obsolescence reserves of $3.0 million and $6.3 million as of September 30, 2022 and December 31, 2021, respectively. The Company recognized $0.6 million and $1.0 million of obsolescence expense during the three and nine months ended September 30, 2021, respectively.
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
(5)    Long-Term Debt
Long-term debt at September 30, 2022 and December 31, 2021 consisted of the following:
(Thousands of Dollars)
September 30,
2022
December 31,
2021
2018 Term Loan Facility
$ 335,125  $ 337,750 
 2021 Equipment Loan 33,162  41,321 
Other long-term debt 339  533 
Less: Unamortized debt discount and debt issuance costs
(3,791) (4,719)
Total debt, net of unamortized debt discount and debt issuance costs
364,835  374,885 
Less: Current portion
(13,849) (13,384)
Long-term debt, net of unamortized debt discount and debt issuance costs
$ 350,986  $ 361,501 
Below is a summary of the Company’s credit facilities outstanding as of September 30, 2022:
(Thousands of Dollars)
2021 Equipment Loan 2019 ABL Facility 2018 Term Loan Facility
Original facility size $ 46,500  $ 450,000  $ 350,000 
Outstanding balance $ 33,162  $ —  $ 335,125 
Letters of credit issued $ —  $ 23,050  $ — 
Available borrowing base commitment n/a $ 371,468  n/a
Interest Rate(1)
5.25  % LIBOR or base rate plus applicable margin LIBOR or base rate plus applicable margin
Maturity Date June 1, 2025 October 31, 2024 May 25, 2025
(1)    London Interbank Offer Rate (“LIBOR”) is subject to a 1.00% floor.
    Maturities of the 2018 Term Loan Facility and the 2021 Equipment Loan (each as defined herein) for the next five years are presented below:

(Thousands of Dollars)
Year-end December 31,
2022 $ 3,760 
2023 15,430 
2024 15,790 
2025 333,646 
2026 — 
$ 368,626 
For additional information regarding the terms of our credit facilities, see Note (8) Long-Term Debt to the Company’s audited consolidated financial statements contained in its Annual Report on Form 10-K for the year ended December 31, 2021.
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
(6) Significant Risks and Uncertainties
The Company operates in two reportable segments: Completion Services and WC&I, with significant concentration in the Completion Services segment. During the three months ended September 30, 2022 and 2021, sales to Completion Services customers represented 96% and 93% of the Company's consolidated revenue, respectively. During the nine months ended September 30, 2022 and 2021, sales to Completion Services customers represented 95% and 92% of the Company's consolidated revenue.
    The Company depends on its customers' willingness to make operating and capital expenditures to explore for, develop and produce oil and natural gas onshore in the U.S. This activity is driven by many factors, including current and expected crude oil and natural gas prices.
From the end of the fourth quarter of 2019 through mid-August 2020, the U.S. active rig count decreased by 70%, from 805 to 244 rigs before recovering to 351 rigs by the end of 2020, primarily driven by the impact from the COVID-19 pandemic. In 2021, the U.S. active rig count recovery continued, increasing 67% from 351 rigs at the end of 2020 to 586 rigs by the end of 2021.
This backdrop drastically impacted the demand for U.S. Completion Services and resulted in increased demand for our services throughout 2021 relative to 2020. By the end of 2021, we started to see signs of improving supply/demand dynamics for U.S. onshore completion services, which resulted in improved pricing and margins relative to earlier in 2021. These improvements accelerated through 2022 and the Company continued to see disciplined increases in oil supply from the Organization of Petroleum Exporting Countries plus ("OPEC+") and U.S. shale operators through the third quarter of 2022. The Russian invasion of Ukraine continues to increase uncertainty of global supply given the crude oil and natural gas that is exported out of Russia.
The magnitude, cadence, and resilience of activity and margin improvement is uncertain and dependent on a range of factors, including supply chain disruptions, inflationary pressures, COVID-19 demand resolution, and the ongoing impact of geopolitical tensions on the global economy.
     Significant customers are those that individually account for 10% or more of the Company's consolidated revenue or total accounts receivable. For the three months ended September 30, 2022, there were no customers that were considered significant. For the nine months ended September 30, 2022, there were no customers that were considered significant. For the three months ended September 30, 2021, the Company had one significant customer in our completions services segment that represented 15% or $60.8 million of the Company's consolidated revenue. For the nine months ended September 30, 2021, the Company had one significant customer in our completions services segment that represented 12% or $113.6 million of the Company's consolidated revenue.
For the three and nine months ended September 30, 2022, there were no suppliers that individually represented more than 5% of the Company's overall purchases. For the three months ended September 30, 2021, purchases from the Company's top supplier represented 5% of the Company's overall purchases, while for the nine months ended September 30, 2021, the Company's top supplier represented approximately 6% of the Company's overall purchases.
(7) Derivatives
    The Company uses interest-rate-related derivative instruments to manage its variability of cash flows associated with changes in interest rates on its variable-rate debt.
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
On March 9, 2020, the Company sold its Well Support Services ("WSS") segment to Basic Energy Services, Inc. (“Basic”) for $93.7 million of total proceeds, including cash and $34.4 million of par value Senior Secured Notes (the "WSS Notes"), with 10.75% coupon rate, previously issued by Basic. Under the terms of the agreement, the WSS Notes were accompanied by a make-whole guarantee at par value, which guaranteed the payment of $34.4 million to the Company after the WSS Notes were held to the one-year anniversary of March 9, 2021. The cash equivalent make-whole was issued under a fund guarantee by Ascribe III Investments LLC ("Ascribe"), a private equity investment firm with approximately $1.0 billion in assets under management. In the event of a Basic restructuring or a credit rating downgrade in conjunction with a change in control prior to the one year anniversary, the make-whole guarantee would accelerate the WSS Notes to par value of $34.4 million. The Company was entitled to semi-annual interest payments on the WSS Notes based on the 10.75% annual coupon throughout the holding period. The Company identified the make-whole guarantee as an embedded derivative and bifurcated the valuation of the WSS Note and the make-whole guarantee. The Company elected the fair value option for the WSS Notes at the inception of the transaction. The fair value of the WSS Notes and the make-whole guarantee were remeasured at fair value at the end of each reporting period. On March 31, 2021, the Company received a $34.4 million cash payment from Ascribe in full settlement of the WSS Notes and the make-whole guarantee. At the time of the cash payment, the WSS Notes and make-whole guarantee had a fair value of $33.6 million, resulting in a realized gain on settlement of $0.8 million. This gain is recorded within other income (expense) on the Consolidated Statements of Operations and Comprehensive Income (Loss).
    On May 25, 2018, the Company and certain subsidiaries of the Company as guarantors, entered into a term loan facility (the "2018 Term Loan Facility"). The 2018 Term Loan Facility had an initial aggregate principal amount of $350.0 million and proceeds were used to repay the Company's pre-existing 2017 term loan facility. The 2018 Term Loan Facility has a variable interest rate based on LIBOR, subject to a 1.0% floor. In June 2018, the Company executed a new off-market interest rate swap effective through March 31, 2025 to hedge 50% of its expected LIBOR exposure matching the swap to the 1-month LIBOR, 1% floor, of the 2018 Term Loan Facility, and terminated the pre-existing interest rate swaps. The new interest rate swap was designated in a new cash flow hedge relationship.
    The following tables present the fair value of the Company's derivative instrument on a gross and net basis as of the periods shown below:
(Thousands of Dollars)
Derivative
designated as
hedging
instruments
Derivative
not
designated as
hedging
instruments
Gross Amounts
of Recognized
Assets and
Liabilities
Gross
Amounts
Offset in the
Balance
Sheet
(1)
Net Amounts
Presented in
the Balance
Sheet
(2)
As of September 30, 2022:
Other current asset $ 2,928  $ —  $ 2,928  $ —  $ 2,928 
Other noncurrent asset 3,747  —  3,747  —  3,747 
As of December 31, 2021:
Other current liability
(2,787) —  (2,787) —  (2,787)
Other noncurrent liability
$ (3,747) $ —  $ (3,747) $ —  $ (3,747)

(1)
Agreements are in place that allow for the financial right of offset for derivative assets and derivative liabilities at settlement or in the event of a default under the agreements.
(2) There are no amounts subject to an enforceable master netting arrangement that are not netted in these amounts. There are no amounts of related financial collateral received or pledged.
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
The following table presents gains and losses for the Company's interest rate derivative designated as cash flow hedges (in thousands of dollars):
Three Months Ended
September 30,
Nine Months Ended
September 30,
2022 2021 2022 2021 Location
Amount of gain recognized in total other comprehensive income (loss) on derivative $ 4,421  $ (46) $ 11,598  $ 785  OCI
Amount of loss reclassified from accumulated other comprehensive income (loss) into earnings $ (264) $ (694) $ (1,642) $ (2,043) Interest Expense
The gain (loss) recognized in other comprehensive income (loss) for the derivative instrument is presented within hedging activities in the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss).
There were no gains or losses recognized in earnings as a result of excluding amounts from the assessment of hedge effectiveness. Based on recorded values as of September 30, 2022, $2.2 million of net gains will be reclassified from accumulated other comprehensive income (loss) into earnings within the next 12 months.
See Note (8) Fair Value Measurements and Financial Information for discussion on fair value measurements related to the Company's derivative instruments.
(8) Fair Value Measurements and Financial Information
The Company discloses the required fair values of financial instruments in its assets and liabilities under the hierarchy guidelines, in accordance with GAAP. As of September 30, 2022, the Company's financial instruments consisted of cash and cash equivalents, accounts receivable, equity security investments, accounts payable, accrued expenses, derivative instruments, long-term debt and lease obligations. As of September 30, 2022 and December 31, 2021, the carrying values of the Company's financial instruments, included in its Condensed Consolidated Balance Sheets, approximated or equaled their fair values.
Recurring Fair Value Measurement
As of September 30, 2022, the Company had two financial instruments measured at fair value on a recurring basis which are its interest rate derivative (see Note (7) Derivatives above) and the earnout payments. Additionally, during the nine months ended September 30, 2022, the Company held an equity security investment composed primarily of common equity shares and warrants in a publicly traded company, in addition to an immaterial balance related to contingent value rights ("CVRs"). As of September 30, 2022, the Company sold all of its common equity shares and warrants and its investment in the CVRs has matured and no longer holds any value. The equity security investment was presented within other current assets, the interest rate derivative is presented within other current assets and other noncurrent assets, and the earnout payments are presented within accrued expenses in the consolidated balance sheets.
The fair market value of the interest rate swap reflected on the consolidated balance sheets as of September 30, 2022 and December 31, 2021 was determined using industry-standard models that consider various assumptions, including current market and contractual rates for the underlying instruments, time value, implied volatilities, nonperformance risk, as well as other relevant economic measures. Substantially all of these inputs are observable in the marketplace through the full term of the instrument and can be supported by observable data.
The following tables present the placement in the fair value hierarchy of assets and liabilities that were measured at fair value on a recurring basis at September 30, 2022 and December 31, 2021 (in thousands of dollars):
Fair value measurements at reporting date using
September 30, 2022 Level 1 Level 2 Level 3
Assets:
Interest rate derivative $ 6,675  $ —  $ 6,675  $ — 
Liabilities:
 Earnout Payments $ (68,492) $ —  $ (30,582) $ (37,910)
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
Fair value measurements at reporting date using
December 31, 2021 Level 1 Level 2 Level 3
Assets:
Equity security investment $ 7,743  $ 7,743  $ —  $ — 
Liabilities:
Earnout payments (11,795) —  —  (11,795)
Interest rate derivative
$ (6,534) $ —  $ (6,534) $ — 
The fair value of the equity security investment is measured at the end of each reporting period. Gains and losses recognized in relation to the change in fair value of the equity security investment are recognized in other income (expense), net in the condensed consolidated statements of operations and comprehensive income (loss). The Company sold the large majority of its investment, with a book value of $10.3 million during the nine months ended September 30, 2022 for $12.4 million, which resulted in a realized gain of $2.1 million. As of September 30, 2022, the remainder of the Company's investment, which consisted of the CVRs, had no carrying value.
The fair value of the earnout payments are measured at the end of each reporting period. Gains and losses recognized in relation to the change in fair value of the earnout payments are recognized in Merger and integration in the Condensed Consolidated Statements of Operations and Comprehensive Income (Loss). See Note (3) for further discussion. The total increase in fair value of the earnout payment was $27.1 million and $59.1 million during the three and nine months ended September 30, 2022, respectively. As of September 30, 2022, $30.6 million of the earnout payments were based on actual results achieved during the performance period ended September 30, 2022 and were therefore considered Level 2 fair value measurements. During the nine months ended September 30, 2022, the Company paid $2.5 million related to the performance period ended December 31, 2021.
Credit Risk
The Company's financial instruments exposed to concentrations of credit risk consist primarily of cash and cash equivalents, the derivative contract and trade receivables.
The Company's cash balances on deposit with financial institutions totaled $250.2 million and $110.7 million as of September 30, 2022 and December 31, 2021, respectively, which exceeded Federal Deposit Insurance Corporation insured limits. The Company regularly monitors these institutions' financial condition.
The credit risk from the derivative contract derives from the potential failure of the counterparty to perform under the terms of the derivative contract. The Company minimizes counterparty credit risk in the derivative instrument by entering into the transaction with a high-quality counterparty, whose Standard & Poor's credit rating is higher than BBB. The derivative instrument entered into by the Company does not contain credit-risk-related contingent features.
The majority of the Company's trade receivables have payment terms of 30 to 60 days. Significant customers are those that individually account for 10% or more of the Company's consolidated revenue or total accounts receivable. As of September 30, 2022, there was one customer that were considered significant that represented 12% or $41.4 million of the Company's total trade receivables. As of December 31, 2021, trade receivables from the Company's one significant customer individually represented 17% or $42.2 million of the Company's total trade receivables.
The Company mitigates the associated credit risk by performing credit evaluations and monitoring the payment patterns of its customers. The Company has a process in place to collect substantially all receivables within 30 to 60 days of aging. As of September 30, 2022, the Company had $2.8 million in allowance for credit losses. As of December 31, 2021, the Company had $1.9 million in allowance for credit losses.
The Company recognized $1.2 million and $1.0 million of bad debt expense, net of recoveries during the three and nine months ended September 30, 2022. During the three and nine months ended September 30, 2021, the Company recognized $0.9 million and $2.1 million of bad debt expense, net of recoveries.
(9) Stock-Based Compensation
Effective as of October 31, 2019, the Company (i) amended and restated the Keane Group, Inc. Equity and Incentive Award Plan under the name NexTier Oilfield Solutions Inc. Equity and Incentive Award Plan (“Equity and Incentive Award Plan”), and (ii)
24


NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
assumed and amended and restated the C&J Energy Services, Inc. 2017 Management Incentive Plan under the name NexTier Oilfield Solutions Inc. (Former C&J Energy) Management Incentive Plan (collectively with the Equity and Incentive Award Plan, the “Equity Award Plans”).
As of September 30, 2022, the Company has five types of stock-based compensation outstanding under its Equity Award Plans: (i) RSAs issued to independent directors and certain executives and employees, (ii) RSUs issued to executive officers and key management employees, (iii) non-qualified stock options issued to executive officers, (iv) PSUs issued to executive officers and key management employees, (v) and PUs issued to executive officers and key management employees.
The following table summarizes stock-based compensation costs for the three and nine months ended September 30, 2022 and 2021 (in thousands of dollars):
Three Months Ended
September 30,
Nine Months Ended
September 30,
2022 2021 2022 2021
Liability-classified awards
Cash-settled awards $ 748  $ —  $ 2,381  $ — 
Equity-classified awards
Restricted stock awards 310  300  938  1,065 
Restricted stock time-based unit awards 4,796  4,100  15,216  10,318 
Non-qualified stock options —  —  —  76 
Restricted stock performance-based unit awards 2,013  2,950  6,327  5,983 
Stock-based compensation cost 7,867  7,350  24,862  17,442 
Tax Benefit(1)
(1,002) (1,151) (3,561) (3,573)
Stock-based compensation cost, net of tax $ 6,865  $ 6,199  $ 21,301  $ 13,869 
(1) The Company is in a valuation allowance position and any tax benefit for stock-based compensation will be offset by the change in valuation allowance.
Cash-settled awards
During the first quarter of 2022, the Company issued 1,009,737 PUs to executive officers under its Equity and Incentive Awards Plan. These PUs will be settled in cash at the end of the performance period, December 31, 2024, and are classified as liability awards, which are remeasured at fair value at each reporting period. The fair value of these awards as of September 30, 2022 was $9.3 million. The Company recognizes compensation cost for the changes in fair value pro-rated for the portion of the requisite service period rendered. During the three and nine months ended September 30, 2022, the Company recognized $0.7 million and $2.4 million in compensation costs related to these awards, respectively.
(10) Earnings per Share
Basic income or (loss) per share is based on the weighted average number of common shares outstanding during the period. Diluted income or (loss) per share includes additional common shares that would have been outstanding if potential common shares with a dilutive effect, such as stock awards from the Equity Awards Plans, had been issued. Anti-dilutive securities represent potentially dilutive securities which are excluded from the computation of diluted income or (loss) per share as their impact would be anti-dilutive.
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
A reconciliation of the numerators and denominators used for the basic and diluted net income (loss) per share computations is as follows (in thousands of dollars):
        
Three Months Ended
September 30,
Nine Months Ended
September 30,
2022 2021 2022 2021
Numerator:
Net Income (loss) $ 104,734  $ (43,994) $ 181,984  $ (130,277)
Denominator:
Basic weighted-average common shares outstanding(1)
244,686 224,481  243,980 218,499 
Dilutive effect of restricted stock awards granted to Board of Directors 104 —  142 214 
Dilutive effect of time-based restricted stock awards granted under the Equity Plan 4,654 1,166  4,596 957 
Dilutive effect of performance-based restricted stock awards granted under the Equity Plan 1,377  511  1,146 321 
Diluted weighted-average common shares outstanding(1)
250,821  226,158  249,864  219,991 
(1) As a result of the net loss incurred by the Company for the three and nine months ended 2021, the calculation of diluted net loss per share gives no consideration to the potentially anti-dilutive securities shown in the above reconciliation, and as such is the same as basic net loss per share.
(11) Commitments and Contingencies
As of September 30, 2022 and December 31, 2021, the Company had $5.9 million and $1.0 million of deposits on equipment, respectively. Outstanding purchase commitments on equipment were $148.8 million and $54.1 million, as of September 30, 2022 and December 31, 2021, respectively.
As of September 30, 2022, the Company had a letter of credit of $23.1 million under the 2019 ABL Facility (as defined herein).
Aggregate minimum commitments under long-term raw material supply contracts for the next five years as of September 30, 2022 are listed below:
(Thousands of Dollars)
2022 $ 16,408 
2023 19,500 
2024 2,610 
2025 1,000 
2026 — 
$ 39,518 
Litigation
From time to time, the Company is subject to legal and administrative proceedings, settlements, investigations, claims and actions, as is typical of the industry. These claims include, but are not limited to, contract claims, environmental claims, employment related claims, claims alleging injury or claims related to operational issues and motor vehicle accidents. The Company's assessment of the likely outcome of litigation matters is based on its judgment of a number of factors, including experience with similar matters, past history, precedents, relevant financial information and other evidence and facts specific to the matter. In accordance with GAAP, the Company accrues for contingencies where the occurrence of a material loss is probable and can be reasonably estimated, based on the Company's best estimate of the expected liability and the Company may record an offsetting receivable to the extent such liability is recoverable from insurance. The Company may increase or decrease its legal accruals in the future, on a matter-by-matter basis, to account for developments in such matters. Notwithstanding the uncertainty as to the final outcome and based upon the information currently available to it, the Company does not currently believe these matters in aggregate will have a material adverse effect on its financial position, results of operations or liquidity.
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
Environmental
The Company is subject to various federal, state and local environmental laws and regulations that establish standards and requirements for protection of the environment. The Company cannot predict the future impact of such standards and requirements, which are subject to change and can have retroactive effectiveness. The Company continues to monitor the status of these laws and regulations. Currently, the Company has not been fined, cited or notified of any environmental violations that would have a material adverse effect upon its financial position, liquidity or capital resources. However, management does recognize that by the very nature of the Company's business, material costs could be incurred in the near term to maintain compliance. The amount of such future expenditures is not determinable due to several factors, including the unknown magnitude of possible regulation or liabilities, the unknown timing and extent of the corrective actions which may be required, the determination of the Company's liability in proportion to other responsible parties and the extent to which such expenditures are recoverable from insurance or through indemnification.
Regulatory Audits
The Company is subject to routine audits by taxing authorities. As of December 31, 2020, the Company had recorded estimates of potential assessments for each audit totaling in the aggregate approximately $33.0 million. For one audit, in particular, the Company disagreed with many aspects of the state’s assessment and began to contest the state’s position through administrative procedures. The Company received a final settlement offer from Texas Attorney General Office on September 8, 2021 for $3.7 million, which resulted in an reduction to the accrual of $2.8 million and $24.9 million during the three and nine months ended September 30, 2021, respectively. This aggregate reduction was recorded in selling, general and administrative expenses in the consolidated statements of operations and comprehensive loss of 2021.
As of September 30, 2022, the Company had recorded estimates of potential assessments, the majority of which is related to an estimate of $14.8 million of potential assessment and exposures for all taxing jurisdictions related to the Alamo Acquisition. As of September 30, 2022, the Company also has an offsetting indemnification receivable of $14.8 million from the former owner of Alamo, recorded pursuant to the Purchase Agreement, in prepaids and other current assets in the Condensed Consolidated Balance Sheet. Both the estimated liability and indemnification receivable of $14.8 million were recorded in the purchase price allocation at the time of the Alamo Acquisition in 2021. During the nine months ended September 30, 2022, the Company obtained additional information that resulted in a reduction of the Company's accrual and offsetting indemnification receivable related to this audit by $2.9 million. There was no change to the Company's accrual during the three months ended September 30, 2022.
(12) Related Party Transactions
Cerberus Operations and Advisory Company, Cerberus Capital Management, L.P., and Cerberus Technology Solutions LLC, affiliates of the Company's principal equity holder, provide certain consulting services to the Company. The Company paid $0.1 million and $0.1 million during the three months ended September 30, 2022 and 2021 respectively for these services. The Company paid $0.5 million and $0.3 million during the nine months ended September 30, 2022 and 2021, respectively, for these services.
As part of the Purchase Agreement, the Company agreed to provide certain post-closing services to Alamo Frac Holdings, LLC valued at $30.0 million in the aggregate. During the three months ended September 30, 2022, the Company did not provide any services to Alamo Frac Holdings, LLC as part of the Purchase Agreement. During the nine months ended September 30, 2022, the Company provided $2.4 million of services to Alamo Frac Holdings, LLC. The Company has a remaining customer contract liability related to these services of $21.3 million as of September 30, 2022.
(13) Business Segments
In accordance with ASC 280, "Segment Reporting", the Company routinely evaluates whether its separate segments have changed. This determination is made based on the following factors: (i) the Company’s chief operating decision maker (“CODM”) is currently managing each operating segment as a separate business and evaluating the performance of each segment and making resource allocation decisions distinctly and expects to do so for the foreseeable future, and (ii) discrete financial information for each operating segment is available.
The following is a description of each reportable segment:
Completion Services
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
 The Company’s Completion Services segment consists of the following businesses and service lines: (i) fracturing services; (ii) wireline and pumpdown services; and (iii) completion support services, which includes the Company's research and technology department.
Well Construction and Intervention Services
 Following the sale of the Company's coiled tubing assets as described below, the Company’s WC&I Services segment consists of the cementing services service line.
On August 1, 2022, the Company sold its coiled tubing assets to Gladiator for a cash purchase price of $21.6 million, which resulted in a gain on sale of assets of $11.6 million. The divestiture of non-core assets is consistent with the Company’s strategy to repurpose capital towards the highest return projects that fit the Company’s strategy around wellsite integration, while also strengthening liquidity. For additional information, see Note (2) Summary of Significant Accounting Policies.
The following tables present financial information with respect to the Company’s segments. Corporate and Other represents costs not directly associated with a segment, such as interest expense, income taxes and corporate overhead. Corporate assets include cash, deferred financing costs, derivatives and entity-level machinery equipment.
(Thousands of Dollars)
Three months ended September 30, Nine Months Ended September 30,
2022 2021 2022 2021
Operations by business segment
Adjusted gross profit:
Completion Services(1)
$ 205,730  $ 46,184  $ 496,794  $ 81,959 
WC&I(1)
7,597  2,905  19,966  7,337 
Total adjusted gross profit $ 213,327  $ 49,089  $ 516,760  $ 89,296 
(1)    Adjusted gross profit at the segment level is not considered to be a non-GAAP financial measure as it is the Company's segment measure of profitability and is required to be disclosed under GAAP pursuant to ASC 280. Adjusted gross profit is defined as revenue less cost of services, further adjusted to eliminate items in cost of services that management does not consider in assessing ongoing performance. 
(Thousands of Dollars)
Three Months Ended September 30, 2022 Nine Months Ended September 30, 2022
Completion Services
WC&I
Total
Completion Services
WC&I
Total
Revenue
$ 857,751  $ 38,259  $ 896,010  $ 2,261,420  $ 112,545  $ 2,373,965 
Cost of Services
652,021  30,662  682,683  1,764,626  92,579  1,857,205 
Gross profit excluding depreciation and amortization
205,730  7,597  213,327  496,794  19,966  516,760 
Adjusted gross profit $ 205,730  $ 7,597  $ 213,327  $ 496,794  $ 19,966  $ 516,760 



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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
(Thousands of Dollars)
Three Months Ended
September 30, 2021
Nine Months Ended
September 30, 2021
Completion Services
WC&I
Total
Completion Services
WC&I
Total
Revenue
$ 366,067  $ 27,097  $ 393,164  $ 843,887  $ 69,824  $ 913,711 
Cost of Services
320,297  24,340  344,637  768,562  63,112  831,674 
Gross profit excluding depreciation and amortization
45,770  2,757  48,527  75,325  6,712  82,037 
Management adjustments associated with cost of services(1)
414  148  562  6,634  625  7,259 
Adjusted gross profit $ 46,184  $ 2,905  $ 49,089  $ 81,959  $ 7,337  $ 89,296 
(1)    Adjustments relate to market-driven severance, leased facility closures, and restructuring costs incurred as a result of significant declines in crude oil prices resulting from demand destruction from the COVID-19 pandemic and global oversupply of crude oil.
(Thousands of Dollars)
September 30, 2022 December 31, 2021
Total assets by segment:
Completion Services $ 1,409,518  $ 1,201,265 
WC&I 37,642  60,195 
Corporate and Other 355,164  196,121 
Total assets $ 1,802,324  $ 1,457,581 
Goodwill by segment:
Completion Services $ 192,780  $ 192,780 
WC&I —  — 
Corporate and Other —  — 
Total goodwill $ 192,780  $ 192,780 
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NEXTIER OILFIELD SOLUTIONS INC. AND SUBSIDIARIES
Notes to the Unaudited Condensed Consolidated Financial Statements
(14) New Accounting Pronouncements
(a) Recently Adopted Accounting Standards
In July 2021, the Financial Accounting Standards Board ("FASB") issued ASU 2021-05 "Leases (Topic 842) Lessors—Certain Leases with Variable Lease Payments" ("ASU 2021-05"). ASU 2021-05 allows a lessor to classify and account for a lease with variable lease payments that doesn't depend on an index or rate as an operating lease if both: a) The lease would’ve been classified as a sales-type lease or a direct-financing lease in accordance with the lease classification guidance in Topic 842; and b) The lessor would’ve otherwise recognized a day-one loss. This standard was effective for fiscal years beginning after December 15, 2021. The Company adopted this standard on January 1, 2022, and there was no material impact on the financial statements.
In August 2020, the FASB issued ASU 2020-06 “Debt—Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging—Contracts in Entity's Own Equity (Subtopic 815-40)” (“ASU 2020-06”). ASU 2020-06 simplifies the guidance on the issuer's accounting for convertible debt instruments and convertible preferred stock. The Company adopted this standard on January 1, 2022, and there was no material impact on the financial statements.
In January 2020, the FASB issued ASU 2020-01, “Investments—Equity Securities (Topic 321), Investments—Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815)”, which clarifies the interaction between the accounting for investments in equity securities, investment in equity method and certain derivatives instruments. This standard is expected to reduce diversity in practice and increase comparability of the accounting for these interactions. The Company adopted this standard on January 1, 2022, and there was no material impact on the financial statements.
(b) Recently Issued Accounting Standards
In October 2021, the FASB issued ASU 2021-08 “Business Combinations (Topic 805) Accounting for Contract Assets and Contact Liabilities from Contracts with Customers” ("ASU 2021-08"). ASU 2021-08 requires acquiring entities to apply Topic 606 to recognize and measure contract assets and contract liabilities in a business combination. This standard is effective for fiscal years beginning after December 15, 2022. The Company does not expect ASU 2021-08 to have any impact on its consolidated financial statements.
In January 2021, the FASB issued ASU 2021-01 “Reference Rate Reform (Topic 848)” ("ASU 2021-01"). ASU 2021-01 expands on the GAAP guidance on contract modifications and hedge accounting related to the expected market transition from the LIBOR and other interbank offered rates to alternative reference rates. This standard was effective beginning on March 12, 2020, and the Company may elect to apply the amendments prospectively through December 31, 2022. The Company does not expect ASU 2021-01 to have any impact on its consolidated financial statements.
In March 2020, the FASB issued ASU 2020-04, “Reference Rate Reform (Topic 848),” which is intended to provide temporary optional expedients and exceptions to the GAAP guidance on contract modifications and hedge accounting to ease the financial reporting burdens related to the expected market transition from the LIBOR and other interbank offered rates to alternative reference rates. This standard was effective beginning on March 12, 2020, and the Company may elect to apply the amendments prospectively through December 31, 2022. The Company does not expect ASU 2021-04 to have any impact on its consolidated financial statements.
(15) Subsequent Events
On October 19, 2022, the Company authorized a shareholder return program, under which the Company may use a total of up to $250 million to repurchase issued and outstanding shares through December 31, 2023.
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis of the financial condition and results of operations should be read in conjunction with the unaudited condensed consolidated financial statements and the related condensed footnotes included within Part I, "Item 1. Financial Statements" in this Quarterly Report on Form 10-Q, as well as our Annual Report on Form 10-K for the year ended December 31, 2021. For additional information related to forward looking statements, please see “Cautionary Statement Regarding Forward-Looking Statements and Information,” which immediately follows the table of contents of this Quarterly Report on Form 10-Q.
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ORGANIZATIONAL OVERVIEW
NexTier Oilfield Solutions Inc. is a predominately U.S. land oilfield service company, with a diverse set of well completion and production services across a variety of active and demanding basins. The Company is organized into two reportable segments:
Completion Services, which consists of the following businesses and services lines: (i) hydraulic fracturing; (ii) wireline and pumpdown services; (iii) Power Solutions natural gas fueling business; and (iv) completion support services, which includes the Company's research and technology department.
WC&I, which, following the sale of its coiled tubing assets during the third quarter of 2022, consists of the cementing services service line.
OPERATIONAL OVERVIEW
Market Trends and Influences
We provide our services in several of the most active basins in the United States, including the Permian, the Marcellus Shale/Utica, the Eagle Ford, Mid-Continental, Haynseville, and the Bakken/Rockies. The high density of our operations in the basins in which we are most active provides us the opportunity to leverage our fixed costs and to quickly respond with what we believe are highly efficient, integrated solutions that are best suited to address customer requirements.
Activity within our business segments is significantly influenced by spending on upstream exploration, development and production programs by our customers. Thus, our financial performance is affected by rig and well counts in North America, as well as oil and natural gas prices, which are discussed in more detail below. Also driving our activity is the status of the global economy, which is a major factor on oil and natural gas demand. Some of the more significant determinants of current and future spending levels of our customers are oil and natural gas prices, global oil supply and demand, supply chain disruptions, the world economy, rising interest rates, the availability of credit, government regulation and global stability, which together drive worldwide drilling activity.
According to the weekly Baker Hughes Incorporated rig count information, total North America rig count during the third quarter of 2022 averaged 761 rigs, reflecting an increase of approximately 7% as compared to the second quarter 2022 average of 713 rigs, but is still approximately 3% below the pre-COVID first quarter 2020 average of 785 rigs. North America rig count exited the third quarter of 2022 at 765 rigs. The increase as compared to the second quarter 2022 average was driven by supportive commodity prices given global undersupply. WTI prices entered the third quarter of 2022 at $105.76 and exited the quarter 25% lower at $79.49. Henry Hub Natural gas prices were up 25% from $5.42 on June 30, 2022 to $6.77 on September 30, 2022.
In the second quarter of 2022, we continued to see disciplined increases in oil supply from OPEC+ and U.S. shale operators, however, in October 2022 OPEC+ indicated it would reduce oil production. The Russian invasion of Ukraine continues to increase uncertainty of global supply given the supply of crude oil and natural gas that is exported from Russia.
U.S. onshore completion activity growth slowed during the quarter, a function of very high utilization of equipment. We deployed one additional frac fleet at the end of Q1 and have not deployed any additional horsepower since then. Demand for our services was strong throughout the quarter, and efficiency improved. We expect fourth quarter activity will be impacted by typical holiday related slowdowns. Continued strength in customer activity and utilization remains dependent on macro conditions, including commodity prices, changing political climate, response to the COVID-19 pandemic (including any resurgences in the U.S. and abroad), continued focus on capital discipline, seasonality and potential lasting changes that a prolonged or resurging pandemic may have on supply and demand worldwide.
In addition, we have started to see improvement in pricing across almost all of our services. Overall economic conditions in the market have continued to improve the profitability of the fleet.
Furthermore, as operators are looking for opportunities to improve well performance and lower costs through innovative techniques, we are seeing a rise in operator initiatives such as simulfrac techniques (we generally refer to these types of initiatives as increasing “frac intensity”). Simulfrac is a process of fracking two or more wells at the same time instead of a single well, for the purpose of increasing operational efficiencies and contributing to well cost savings. These techniques require multi-well pads and advanced complex completion designs, resulting in, among other things, adaption costs, an increase in the amount of equipment related to a particular job, an increase in commodities (such as proppant, logistics, and chemicals), and enhanced maintenance practices and procedures. The increasing complexity and resources required by evolving frac intensity, such as simulfrac, results in the need to fine-tune our approach in the related commercial agreements, especially around sharing the value created and the commercial risks of these enhanced operations. We're continuing to work with our customers to utilize experiences on these operations, including Simulfrac, to hone our commercial agreements going forward.

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We are constantly assessing our approach to ensure that our team and our equipment meets the evolving demands of our customers. Customers are increasingly looking for ways to lower their carbon footprint by lower emissions associated with their drilling and completion activity. We have invested to upgrade more than half of our fleet to be able to operate using natural gas as a primary fuel source. These dual fuel fleets can be powered using both diesel and natural gas as a fuel source. In addition to lowering emissions, at current diesel and natural gas prices, using natural gas can lower the cost to operate a dual fuel fleet relative to a conventional diesel fleet. In addition, we plan to deploy our first electric fleet in 2023.

As indicated previously, macro-economic factors are resulting in inflation of materials and other costs, such as employee compensation, contract services, commodity prices and communications expenses. While inflation increases our operating costs, the impact of commodity inflation on the Company to date has been significantly mitigated by the Company's ability to adjust pricing to pass the impact of inflation through to its customers. Additionally, we, our suppliers and contractors are facing a highly competitive domestic labor market. These labor market dynamics create wage inflation, increase recruiting costs due to elevated employee attrition and, with respect to driver shortages, may negatively impact or increase the cost of our logistics service for our customers. The rate and scope of these various aspects of inflation may continue to impact our costs, which may not be readily recoverable in the prices of our services. At this time, we expect this trend to continue through the remainder of 2022. As such, its full financial impact on our business is impractical to quantify at this time.

Global market supply chain and logistics constraints have also impacted our suppliers. We have begun to see a more pronounced delay in lead times for certain components used in equipment, parts and supplies. Additionally, some shipments from overseas suppliers are experiencing transportation delays due to a lack of available containers and a backlog at incoming ports of entry. These delays in shipments could impact our availability to secure parts and inventory, although the ultimate impact is impractical to quantify at this time.

Utilization Tendencies

Historically, our utilization levels have been highly correlated to U.S. onshore spending by our customers, which is heavily driven by the price of oil and natural gas. Generally, as capital spending by our customers increases, drilling, completion and production activity also increases, resulting in increased demand for our services, and therefore more days or hours worked (as the case may be). Conversely, when drilling, completion and production activity levels decline due to lower spending by our customers, we generally provide fewer services, which results in fewer days or hours worked (as the case may be).
Given the volatile and cyclical nature of activity drivers in the U.S. onshore oilfield services industry, coupled with the varying prices we are able to charge for our services and the cost of providing those services, among other factors, operating margins can fluctuate widely depending on supply and demand at a given point in the cycle. Additionally, during periods of decreased spending by our customers and/or high competition, we may be required to discount our rates or provide other pricing concessions to remain competitive and support deployed equipment utilization, which negatively impacts our revenue and operating margins. During periods of pricing weakness for our services, we may not be able to reduce our costs accordingly, and our ability to achieve any cost reductions from our suppliers typically lags behind the decline in pricing for our services, which could further adversely affect our results. Furthermore, when demand for our services increases following a period of low demand, our ability to capitalize on such increased demand may be delayed while we reengage and redeploy equipment and crews that have been idled during a downturn. The mix of customers that we are working for, as well as limited periods of exposure to the spot market, also impacts our deployed equipment utilization. Some smaller operators may not have sufficient programs to support continuous operations or dedicated fleets. To the extent we have a significant percentage of our operations servicing such smaller operators, we may experience lower utilization.
Strategic Direction

We believe that there is competitive value in providing integrated solutions that align the incentives of operators and service providers. We are pursuing opportunities to leverage our investment in our digital program as well as diesel substitution reduction technologies (such as dual fuel and electric fleet capabilities and the sand haul trailers acquired from CIG), to provide a service strategy targeted at achieving emissions reductions, both for us and our customers. Our acquisition of Alamo added 9 hydraulic fracturing fleets, approximately 92% of which are Tier IV dual fuel capable. NexTier's best-in-class digital platform has been applied to the NexTier operating fleets. We have launched our natural gas treatment and delivery (Power Solutions), including natural gas sourcing, compression, transport, decompression, and treatment services, that will power NexTier’s fleet with field gas or compressed natural gas. This service solution seeks to address wellsites where there is not a reliable nearby gas supply, and thus, the full benefit and value of dual fuel or other lower emissions technologies may not otherwise be fully realized. Our integrated natural gas treatment and delivery solution became operational in the second half of 2021. This integrated strategy is designed to provide our customers with a streamlined approach to driving more sustainable, cost effective operations at the wellsite. Given the positive market response, we have continued to invest and grow the Power Solutions footprint. Our acquisition of assets from CIG is in line with our commitment to significantly expand our last mile logistics capabilities.
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We believe our integrated approach and proven capabilities enable us to deliver cost-effective solutions for increasingly complex and technically demanding well completion requirements, which include longer lateral segments, higher pressure rates and proppant intensity and multiple fracturing stages in challenging high-pressure formations. In addition, our technical team and our innovation centers, provide us with the ability to supplement our service offerings with engineered solutions specifically tailored to address customers’ completion requirements and unique challenges. For example, utilizing a lateral science technique resulting in simulfrac stage pairing can reduce the operator’s cost per barrel by taking existing drilling data, analyzing the downhole rock properties, and matching the four or six wells across a simulfrac pad to create an optimized pair for every simulfrac stage. We believe utilization of this technique will ultimately improve injectivity of the frac treatments, improve the long-term production of the treated wells, and lower the equipment costs for each operation. Simulfrac stage pairing can help connect our simulfrac operational experience to real reservoir properties, thereby providing opportunity to deploy a more cost-effective solution that delivers higher production to the operator.
We believe that the safety, quality and efficiency of our service execution and our alignment with customers who recognize the value that we provide are central to our efforts to support utilization and grow our business.
Operating Effectively Through the COVID-19 Pandemic
    We have continued our measures focused on the safety of our partners, employees, and the communities in which we operate, while at the same time seeking to mitigate the impact on our financial position and operations. For additional information regarding the actions we've taken since the onset of the COVID-19 pandemic and the increased risks to our business related to the COVID-19 pandemic can be found in our Annual Report on Form 10-K for the year ended December 31, 2021. While we saw continued recovery from the impacts of the COVID-19 pandemic through the first three quarters of 2022, contingency plans remain in place to address the impact of resurgences of the virus (including as a result of the emergence of new variants and strains of the virus, such as Delta and Omicron).


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RESULTS OF OPERATIONS IN 2022 COMPARED TO 2021
Three Months Ended September 30, 2022 Compared with Three Months Ended September 30, 2021
The following is a comparison of our results of operations for the three months ended September 30, 2022 compared to the three months ended September 30, 2021.
Three Months Ended September 30,
(Thousands of Dollars)
As a % of Revenue
Variance 
Description
2022 2021 2022 2021 $ %
Completion Services $ 857,751  $ 366,067  96  % 93  % $ 491,684  134  %
WC&I 38,259  27,097  % % 11,162  41  %
Revenue
896,010  393,164  100  % 100  % 502,846  128  %
Completion Services 652,021  320,297  73  % 81  % 331,724  104  %
WC&I 30,662  24,340  % % 6,322  26  %
Costs of services
682,683  344,637  76  % 88  % 338,046  98  %
Depreciation and amortization
56,542  44,861  % 11  % 11,681  26  %
Selling, general and administrative expenses
37,415  37,453  % 10  % (38) %
Merger and integration
27,521  4,752  % % 22,769  479  %
Gain on disposal of assets (10,471) (1,133) (1  %) % (9,338) 824  %
Operating income (loss) 102,320  (37,406) 11  % (10  %) 139,726  (374  %)
Other income, net 11,124  585  % % 10,539  1,802  %
Interest expense
(7,150) (6,701) (1  %) (2  %) (449) %
Total other income (expense)
3,974  (6,116) % (2  %) 10,090  (165  %)
Income tax expense (1,560) (472) % % (1,088) 231  %
Net income (loss) $ 104,734  $ (43,994) 12  % (11  %) $ 148,728  (338  %)
Revenue: Total revenue is comprised of revenue from our Completion Services and WC&I segments. Revenue during the three months ended September 30, 2022 increased by $502.8 million, or 128%, to $896.0 million from $393.2 million during the three months ended September 30, 2021. This change in revenue by reportable segment is discussed below.
Completion Services: Revenue for Completion Services during the three months ended September 30, 2022 increased by $491.7 million, or 134%, to $857.8 million from $366.1 million during the three months ended September 30, 2021. The segment revenue increase is primarily attributable to a strong increase in the number of deployed hydraulic fracturing fleets, additional well-site integration and commodities, including our Power Solutions natural gas fueling services, increases in wireline and pump down services, and the Alamo Acquisition on August 31, 2021. Improved market conditions and higher global commodity prices drove increased customer activity across all basins, and we realized strong pricing recovery in all services lines.
Well Construction and Intervention Services: WC&I segment revenue increased $11.2 million, or 41%, to $38.3 million during the three months ended September 30, 2022 from $27.1 million during the three months ended September 30, 2021. The increase in revenue is primarily due to higher customer activity, improved pricing, and increased utilization in our cementing and coil tubing services (prior to the sale of the coiled tubing assets to Gladiator) resulting from improved market conditions and higher global oil and gas commodity prices, offset by the reduction due to the sale of the coil tubing service line in the third quarter of 2022.
Cost of Services: Cost of services during the three months ended September 30, 2022 increased by $338.0 million, or 98%, to $682.7 million from $344.6 million during the three months ended September 30, 2021. The increase is primarily due to significantly increased activity, utilization, and commodity capture, as explained under the "Revenue" caption and its related segment sub-captions above. Pricing improvements coupled with operational efficiencies and process improvements to permanently drive costs out of the organization more than offset the impact of cost inflation, and led to overall costs increasing at a lower rate than revenue increased.
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Equipment Utilization: Depreciation and amortization expense increased $11.7 million, or 26%, to $56.5 million during the three months ended September 30, 2022 from $44.9 million during the three months ended September 30, 2021. The increase in depreciation and amortization is primarily due to additional equipment received in the Alamo Acquisition. Gain on disposal of assets increased by $9.3 million, or 824%, to a gain of $10.5 million during the three months ended September 30, 2022 from $1.1 million during three months ended September 30, 2021.
Selling, general and administrative expense: Selling, general and administrative expense, which represents costs associated with managing and supporting our operations, remained relatively flat at $37.4 million during three months ended September 30, 2022 compared to $37.5 million during the three months ended September 30, 2021.
Merger and integration expense: Merger and integration expense increased by $22.8 million during the three months ended September 30, 2022 to $27.5 million from $4.8 million during the three months ended September 30, 2021. The increase in merger and integration expense is primarily related to the Alamo Acquisition earnout, which was triggered by Alamo achieving certain EBITDA targets pursuant to the Purchase Agreement. The earnout performance period, which goes through December 31, 2022, is still ongoing and changes in the fair value of the earnout are based on actual and projected performance within the performance period, in accordance with the Purchase Agreement.
Effective tax rate: Our effective tax rate on continuing operations for the three months ended September 30, 2022 was 1.5% for $1.6 million of recorded income tax expense. The difference between the effective tax rate and the U.S. federal statutory rate is due to state income taxes and change in valuation allowance. We intend to continue maintaining a full valuation allowance on our deferred tax assets until there is sufficient evidence to support the reversal of all or some portion of these allowances. Release of the valuation allowance would result in the recognition of certain deferred tax assets and a decrease to income tax expense for the period the release is recorded. We continue to rigorously evaluate all available evidence to determine the likelihood of utilizing our net deferred tax assets.
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RESULTS OF OPERATIONS IN 2022 COMPARED TO 2021
Nine Months Ended September 30, 2022 Compared with Nine Months Ended September 30, 2021
The following is a comparison of our results of operations for the nine months ended September 30, 2022 compared to the nine months ended September 30, 2021.
Nine Months Ended September 30,
(Thousands of Dollars)
As a % of Revenue
Variance 
Description
2022 2021 2022 2021 $ %
Completion Services $ 2,261,420  $ 843,887  95  % 92  % $ 1,417,533  168  %
WC&I 112,545  69,824  % % 42,721  61  %
Revenue
2,373,965  913,711  100  % 100  % 1,460,254  160  %
Completion Services 1,764,626  768,562  74  % 84  % 996,064  130  %
WC&I 92,579  63,112  % % 29,467  47  %
Costs of services
1,857,205  831,674  78  % 91  % 1,025,531  123  %
Depreciation and amortization
170,499  131,400  % 14  % 39,099  30  %
Selling, general and administrative expenses
109,129  74,256  % % 34,873  47  %
Merger and integration
60,435  4,930  % % 55,505  1,126  %
Gain on disposal of assets (12,160) (7,742) (1  %) (1  %) (4,418) 57  %
Operating income (loss) 188,857  (120,807) % (13  %) 309,664