Cover Page
Cover Page - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2021 | Mar. 02, 2022 | Jun. 30, 2021 | |
Cover [Abstract] | |||
Document Type | 10-K | ||
Document Annual Report | true | ||
Document Period End Date | Dec. 31, 2021 | ||
Current Fiscal Year End Date | --12-31 | ||
Document Transition Report | false | ||
Entity File Number | 001-37917 | ||
Entity Registrant Name | Mammoth Energy Services, Inc. | ||
Entity Incorporation, State or Country Code | DE | ||
Entity Tax Identification Number | 32-0498321 | ||
Entity Address, Address Line One | 14201 Caliber Drive, | ||
Entity Address, Address Line Two | Suite 300 | ||
Entity Address, City or Town | Oklahoma City, | ||
Entity Address, State or Province | OK | ||
City Area Code | (405) | ||
Local Phone Number | 608-6007 | ||
Entity Address, Postal Zip Code | 73134 | ||
Title of 12(b) Security | Common Stock | ||
Trading Symbol | TUSK | ||
Security Exchange Name | NASDAQ | ||
Entity Well-known Seasoned Issuer | No | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Interactive Data Current | Yes | ||
Entity Filer Category | Accelerated Filer | ||
Entity Small Business | true | ||
Entity Emerging Growth Company | false | ||
ICFR Auditor Attestation Flag | true | ||
Entity Shell Company | false | ||
Entity Public Float | $ 106.6 | ||
Entity Common Stock, Shares Outstanding (in shares) | 46,684,065 | ||
Documents Incorporated by Reference | DOCUMENTS INCORPORATION BY REFERENCE Portions of Mammoth Energy Services, Inc.’s Proxy Statement for the 2022 Annual Meeting of Stockholders are incorporated by reference in Items 10, 11, 12, 13 and 14 of Part III of this Form 10-K. | ||
Entity Central Index Key | 0001679268 | ||
Document Fiscal Year Focus | 2021 | ||
Document Fiscal Period Focus | FY | ||
Amendment Flag | false |
Audit Information
Audit Information | 12 Months Ended |
Dec. 31, 2021 | |
Auditor Information [Abstract] | |
Auditor Firm ID | 248 |
Auditor Name | GRANT THORNTON LLP |
Auditor Location | Oklahoma City, Oklahoma |
CONSOLIDATED BALANCE SHEETS
CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
CURRENT ASSETS | ||
Cash and cash equivalents | $ 9,899 | $ 14,822 |
Short-term investment | 1,762 | 1,750 |
Accounts receivable, net | 407,550 | 393,112 |
Receivables from related parties, net | 88 | 28,461 |
Inventories | 8,366 | 12,020 |
Prepaid expenses | 12,381 | 13,825 |
Other current assets | 737 | 758 |
Total current assets | 440,783 | 464,748 |
Property, plant and equipment, net | 176,586 | 251,262 |
Sand reserves | 64,641 | 65,876 |
Operating lease right-of-use assets | 12,168 | 20,179 |
Intangible assets, net | 2,561 | 4,774 |
Goodwill | 11,717 | 12,608 |
Deferred income tax asset | 8,094 | 0 |
Other non-current assets | 4,342 | 5,115 |
Total assets | 720,892 | 824,562 |
CURRENT LIABILITIES | ||
Accounts payable | 37,560 | 40,319 |
Accrued expenses and other current liabilities | 62,516 | 44,408 |
Current operating lease liability | 5,942 | 8,618 |
Current portion of long-term debt | 1,468 | 1,165 |
Income taxes payable | 42,748 | 34,088 |
Total current liabilities | 150,234 | 128,598 |
Long-term debt, net of current portion | 85,240 | 81,338 |
Deferred income tax liabilities | 865 | 24,741 |
Long-term operating lease liability | 5,918 | 11,377 |
Asset retirement obligations | 3,720 | 4,746 |
Other long-term liabilities | 11,693 | 10,435 |
Total liabilities | 257,670 | 261,235 |
COMMITMENTS AND CONTINGENCIES | ||
Equity: | ||
Common stock, $0.01 par value, 200,000,000 shares authorized, 46,684,065 and 45,769,283 issued and outstanding at December 31, 2021 and 2020 | 467 | 458 |
Additional paid in capital | 538,221 | 537,039 |
Retained earnings (deficit) | (72,535) | 28,895 |
Accumulated other comprehensive loss | (2,931) | (3,065) |
Total equity | 463,222 | 563,327 |
Total liabilities and equity | $ 720,892 | $ 824,562 |
CONSOLIDATED BALANCE SHEETS (Pa
CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares | Dec. 31, 2021 | Dec. 31, 2020 |
Statement of Financial Position [Abstract] | ||
Common stock, par or stated value per share (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 200,000,000 | 200,000,000 |
Common stock, shares, issued (in shares) | 46,684,065 | 45,769,283 |
Common stock outstanding (in shares) | 46,684,065 | 45,769,283 |
CONSOLIDATED STATEMENTS OF COMP
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) shares in Thousands, $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
COST AND EXPENSES | |||
Selling, general and administrative | $ 77,861 | $ 66,427 | $ 49,705 |
Selling, general and administrative - related parties | 385 | 758 | 1,847 |
Depreciation, depletion, amortization and accretion | 78,475 | 95,317 | 117,033 |
Impairment of goodwill | 891 | 54,973 | 33,664 |
Impairment of other long-lived assets | 1,212 | 12,897 | 7,358 |
Operating loss | (128,188) | (149,317) | (128,383) |
OTHER INCOME (EXPENSE) | |||
Interest expense, net | (6,406) | (5,397) | (4,958) |
Other, net | 10,816 | 33,048 | 42,216 |
Other, net - related parties | (515) | 1,890 | 0 |
Total other income | 3,895 | 29,541 | 37,258 |
Loss before income taxes | (124,293) | (119,776) | (91,125) |
Benefit for income taxes | (22,863) | (12,169) | (12,081) |
Net (loss) income | (101,430) | (107,607) | (79,044) |
OTHER COMPREHENSIVE INCOME (LOSS) | |||
Foreign currency translation adjustment, net of tax of ($36), ($54) and ($203), respectively, for 2021, 2020 and 2019 | 134 | 241 | 775 |
Comprehensive loss | $ (101,296) | $ (107,366) | $ (78,269) |
Basic loss per share (in dollars per share) | $ (2.18) | $ (2.36) | $ (1.76) |
Net loss per share (diluted) (in dollars per share) | $ (2.18) | $ (2.36) | $ (1.76) |
Weighted average number of shares outstanding (in shares) | 46,428 | 45,644 | 45,011 |
Weighted average number of shares outstanding, including dilutive effect (in shares) | 46,428 | 45,644 | 45,011 |
Product And Service Including Related Party | |||
REVENUE | |||
Revenue | $ 228,962 | $ 313,076 | $ 625,012 |
COST AND EXPENSES | |||
Total cost and expenses | 357,150 | 462,393 | 753,395 |
Service | |||
REVENUE | |||
Revenue | 182,236 | 234,081 | 452,594 |
COST AND EXPENSES | |||
Cost of revenue | 170,275 | 205,657 | 451,206 |
Product | |||
REVENUE | |||
Revenue | 28,799 | 28,404 | 42,105 |
COST AND EXPENSES | |||
Cost of revenue | 27,520 | 25,946 | 87,812 |
Related parties | |||
COST AND EXPENSES | |||
Selling, general and administrative - related parties | 387 | 758 | 1,847 |
Related parties | Service | |||
REVENUE | |||
Revenue | 15,782 | 43,091 | 102,624 |
COST AND EXPENSES | |||
Cost of revenue | 531 | 418 | 4,770 |
Related parties | Product | |||
REVENUE | |||
Revenue | $ 2,145 | $ 7,500 | $ 27,689 |
CONSOLIDATED STATEMENTS OF CO_2
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Supplemental Income Statement Elements [Abstract] | |||
Tax portion of foreign currency translation adjustment | $ (36) | $ (54) | $ (203) |
Service | |||
Supplemental Income Statement Elements [Abstract] | |||
Depreciation, amortization, and accretion, cost of revenue | 69,401 | 85,481 | 102,901 |
Product | |||
Supplemental Income Statement Elements [Abstract] | |||
Depreciation, amortization, and accretion, cost of revenue | 8,993 | 9,758 | 14,039 |
Related parties | Service | |||
Supplemental Income Statement Elements [Abstract] | |||
Depreciation, amortization, and accretion, cost of revenue | $ 0 | $ 0 | $ 0 |
CONSOLIDATED STATEMENTS OF CHAN
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Thousands | Total | Common Stock | Retained Earnings (Deficit) | Additional Paid-In Capital | Accumulated Other Comprehensive Loss |
Beginning balance (in shares) at Dec. 31, 2018 | 44,877,000 | ||||
Beginning balance at Dec. 31, 2018 | $ 754,052 | $ 449 | $ 226,765 | $ 530,919 | $ (4,081) |
Increase (Decrease) in Partners' Capital [Roll Forward] | |||||
Stock based compensation (in shares) | 232,000 | ||||
Stock based compensation | 4,177 | $ 2 | 4,175 | ||
Net loss | (79,044) | (79,044) | |||
Cash dividends declared | (11,219) | (11,219) | |||
Other comprehensive income | 775 | 775 | |||
Ending balance (in shares) at Dec. 31, 2019 | 45,109,000 | ||||
Ending balance at Dec. 31, 2019 | 668,741 | $ 451 | 136,502 | 535,094 | (3,306) |
Increase (Decrease) in Partners' Capital [Roll Forward] | |||||
Stock based compensation (in shares) | 660,000 | ||||
Stock based compensation | 1,952 | $ 7 | 1,945 | ||
Net loss | (107,607) | (107,607) | |||
Other comprehensive income | $ 241 | 241 | |||
Ending balance (in shares) at Dec. 31, 2020 | 45,769,283 | 45,769,000 | |||
Ending balance at Dec. 31, 2020 | $ 563,327 | $ 458 | 28,895 | 537,039 | (3,065) |
Increase (Decrease) in Partners' Capital [Roll Forward] | |||||
Stock based compensation (in shares) | 915,000 | ||||
Stock based compensation | 1,191 | $ 9 | 1,182 | ||
Net loss | (101,430) | (101,430) | |||
Other comprehensive income | $ 134 | 134 | |||
Ending balance (in shares) at Dec. 31, 2021 | 46,684,065 | 46,684,000 | |||
Ending balance at Dec. 31, 2021 | $ 463,222 | $ 467 | $ (72,535) | $ 538,221 | $ (2,931) |
CONSOLIDATED STATEMENTS OF CH_2
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) | 12 Months Ended |
Dec. 31, 2019$ / shares | |
Statement of Stockholders' Equity [Abstract] | |
Cash dividends declared (in dollars per share) | $ 0.25 |
CONSOLIDATED STATEMENTS OF CASH
CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Cash flows from operating activities | |||
Net loss | $ (101,430,000) | $ (107,607,000) | $ (79,044,000) |
Adjustments to reconcile net loss to cash (used in) provided by operating activities: | |||
Stock based compensation | 1,191,000 | 1,952,000 | 4,177,000 |
Depreciation, depletion, amortization and accretion | 78,475,000 | 95,317,000 | 117,033,000 |
Amortization of coil tubing strings | 0 | 359,000 | 1,641,000 |
Amortization of debt origination costs | 665,000 | 831,000 | 326,000 |
Bad debt expense (recoveries) | 41,662,000 | 21,958,000 | 1,434,000 |
(Gain) loss on disposal of property and equipment | (5,435,000) | (1,379,000) | 55,000 |
Impairment of goodwill | 891,000 | 54,973,000 | 33,664,000 |
Impairment of other long-lived assets | 1,212,000 | 12,897,000 | 7,358,000 |
Inventory obsolescence | 0 | 0 | 1,349,000 |
Deferred income taxes | (32,005,000) | (12,186,000) | (42,639,000) |
Other | (280,000) | 143,000 | 986,000 |
Changes in assets and liabilities: | |||
Accounts receivable, net | (55,898,000) | (32,621,000) | (27,006,000) |
Receivables from related parties | 28,373,000 | (40,333,000) | 3,641,000 |
Inventories | 3,654,000 | 5,103,000 | 830,000 |
Prepaid expenses and other assets | 1,444,000 | 1,996,000 | (1,040,000) |
Accounts payable | (2,982,000) | 2,004,000 | (25,812,000) |
Accrued expenses and other liabilities | 12,380,000 | 3,198,000 | (18,800,000) |
Income taxes payable | 8,658,000 | 648,000 | (71,499,000) |
Net cash (used in) provided by operating activities | (18,865,000) | 6,967,000 | (95,318,000) |
Cash flows from investing activities: | |||
Purchases of property and equipment | (5,843,000) | (6,761,000) | (35,417,000) |
Purchases of property and equipment from related parties | 0 | (76,000) | (344,000) |
Contributions to equity investee | 0 | (490,000) | (680,000) |
Proceeds from disposal of property and equipment | 11,350,000 | 6,782,000 | 3,217,000 |
Purchase of short-term investment | 0 | (1,750,000) | 0 |
Net cash provided by (used in) investing activities | 5,507,000 | (2,295,000) | (33,224,000) |
Cash flows from financing activities: | |||
Borrowings on long-term debt | 73,100,000 | 35,351,000 | 156,000,000 |
Repayments of long-term debt | (68,911,000) | (32,800,000) | (76,000,000) |
Proceeds from sale-leaseback transaction | 9,473,000 | 5,000,000 | 0 |
Payments on sale-leaseback transaction | (2,951,000) | (268,000) | 0 |
Dividends paid | 0 | 0 | (11,219,000) |
Principal payments on financing leases and equipment financing notes | (2,283,000) | (1,966,000) | (2,079,000) |
Debt issuance costs | 0 | (1,051,000) | 0 |
Net cash provided by financing activities | 8,428,000 | 4,266,000 | 66,702,000 |
Effect of foreign exchange rate on cash | 7,000 | 12,000 | 87,000 |
Net (decrease) increase in cash and cash equivalents | (4,923,000) | 8,950,000 | (61,753,000) |
Cash and cash equivalents at beginning of period | 14,822,000 | 5,872,000 | 67,625,000 |
Cash and cash equivalents at end of period | 9,899,000 | 14,822,000 | 5,872,000 |
Supplemental disclosure of cash flow information: | |||
Cash paid for interest | 4,827,000 | 4,729,000 | 4,741,000 |
Cash paid (recovered) for income taxes | 829,000 | (617,000) | 110,848,000 |
Supplemental disclosure of non-cash transactions: | |||
Purchases of property and equipment included in accounts payable | 1,535,000 | 1,312,000 | 2,303,000 |
Right-of-use assets obtained for financing lease liabilities | $ 1,750,000 | $ 2,431,000 | $ 3,721,000 |
Organization and Basis of Prese
Organization and Basis of Presentation | 12 Months Ended |
Dec. 31, 2021 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Organization and Basis of Presentation | Organization and Basis of Presentation The accompanying consolidated financial statements were prepared in accordance with the rules and regulations of the Securities and Exchange Commission, and reflect all adjustments, which in the opinion of management are necessary for the fair presentation of the results. Mammoth Energy Services, Inc. (“Mammoth Inc.”, “Mammoth” or the “Company”), together with its subsidiaries, is an integrated, growth-oriented company serving both the oil and gas and the electric utility industries in North America and US territories. Mammoth Inc.’s infrastructure division provides engineering, design, construction, upgrade, maintenance and repair services to various public and private owned utilities. Its oilfield services division provides a diversified set of services to the exploration and production industry including well completion, natural sand and proppant and drilling services. Additionally, the Company provides aviation services, equipment rentals, crude oil hauling, remote accommodation services and equipment manufacturing. The Company was incorporated in Delaware in June 2016. The following companies (“Operating Entities”) are included in these consolidated financial statements: Bison Drilling and Field Services, LLC (“Bison Drilling”), formed November 15, 2010; Bison Trucking LLC (“Bison Trucking”), formed August 9, 2013; Anaconda Rentals LLC, formerly known as White Wing Tubular Services LLC, formed July 29, 2014; Barracuda Logistics LLC (“Barracuda”), formed October 24, 2014; Mr. Inspections LLC (“MRI”), formed January 25, 2015; Panther Drilling Systems LLC (“Panther”), formed December 11, 2012; Redback Energy Services, LLC (“Redback Energy”), formed October 6, 2011; Redback Coil Tubing, LLC (“Coil Tubing”), formed May 15, 2012; Redback Pump Down Services LLC (“Pump Down”), formed January 16, 2015; Muskie Proppant LLC (“Muskie”), formed September 14, 2011; Stingray Pressure Pumping LLC (“Stingray Pressure Pumping”), acquired November 24, 2014; Silverback Energy LLC (“Silverback”), formerly known as Stingray Logistics LLC, acquired November 24, 2014; Great White Sand Tiger Lodging Ltd. (“Sand Tiger”), formed October 1, 2007; WTL Oil LLC (“WTL”), formerly known as Silverback Energy Services LLC, formed June 8, 2016; Mammoth Equipment Leasing LLC, formed November 14, 2016; Cobra Acquisitions LLC (“Cobra”), formed January 9, 2017; Lion Power Services LLC (“Lion Power”), formerly known as Cobra Energy LLC, formed January 25, 2017; Mako Acquisitions LLC (“Mako”), formed March 28, 2017; Piranha Proppant LLC (“Piranha”), formed March 28, 2017; Higher Power Electrical LLC (“Higher Power”), acquired April 21, 2017; Stingray Energy Services LLC (“SR Energy”), acquired June 5, 2017; Stingray Cementing LLC (“Cementing”), acquired June 5, 2017; Sturgeon Acquisitions LLC (“Sturgeon”), acquired June 5, 2017; Taylor Frac, LLC (“Taylor Frac”), acquired June 5, 2017; Taylor Real Estate Investments, LLC (“Taylor RE”), acquired June 5, 2017; South River Road, LLC (“South River”), acquired June 5, 2017; 5 Star Electric, LLC (“5 Star”), acquired July 1, 2017; Tiger Shark Logistics LLC (“Tiger Shark”), formed October 20, 2017; Cobra Aviation Services LLC (“Cobra Aviation”), formed January 2, 2018; Bison Sand Logistics LLC (“Bison Sand”), formed January 8, 2018; Dire Wolf Energy Services LLC (“Dire Wolf”), formed January 8, 2018; Black Mamba Energy LLC (“Black Mamba”), formed March 28, 2018; Stingray Cementing and Acidizing LLC (“Stingray Cementing and Acidizing”), formerly known as RTS Energy Services LLC (“RTS”), acquired June 15, 2018; Aquahawk Energy LLC (“Aquahawk”), formed June 28, 2018; Ivory Freight Solutions LLC (“Ivory Freight”), formed July 26, 2018; Python Equipment LLC (“Python”), formed December 5, 2018; IFX Transport LLC (“IFX”), formed December 5, 2018; Air Rescue Systems LLC (“ARS”), acquired December 21, 2018; Leopard Aviation LLC (“Leopard”), formed April 29, 2019; Predator Aviation LLC (“Predator Aviation”), formed April 19, 2019; Anaconda Manufacturing LLC (“Anaconda”), formed July 31, 2019; Aquawolf LLC (“Aquawolf”), formed September 25, 2019; and Falcon Fiber Solutions LLC (“Falcon”), formed March 3, 2021. Operations The Company’s infrastructure services include engineering, design, construction, upgrade, maintenance and repair services to the electrical infrastructure industry as well as repair and restoration services in response to storms and other disasters. The Company’s well completion services include equipment and personnel used in connection with the completion and early production of oil and natural gas wells. The Company’s natural sand proppant services include the distribution and production of natural sand proppant that is used primarily for hydraulic fracturing in the oil and gas industry. The Company’s drilling services provide drilling rigs and directional tools for both vertical and horizontal drilling of oil and natural gas wells. The Company also provides other services, including aviation, equipment rentals, remote accommodations and equipment manufacturing. Substantially all of the Company’s operations are in North America. During the periods presented in this report, the Company provided its infrastructure services primarily in the northeastern, southwestern, midwestern and western portions of the United States and in Puerto Rico. The Company’s infrastructure business depends on infrastructure |
Summary of Significant Accounti
Summary of Significant Accounting Policies | 12 Months Ended |
Dec. 31, 2021 | |
Accounting Policies [Abstract] | |
Summary of Significant Accounting Policies | Summary of Significant Accounting Policies Principles of Consolidation The accompanying consolidated financial statements are prepared in accordance with GAAP and include the accounts of the Company and its subsidiaries and the variable interest entities (“VIE”) for which the Company is the primary beneficiary. All material intercompany accounts and transactions between the entities within the Company have been eliminated. Variable Interest Entities The Company consolidates a VIE when it is determined to be the primary beneficiary, which is the party that has both (i) the power to direct the activities that most significantly impact the VIE’s economic performance and (ii) through its interests in the VIE, the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. See Note 11 for more information on the Company’s VIEs. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates include, but are not limited to, the Company's sand reserves and their impact on calculating depletion expense, allowance for doubtful accounts, asset retirement obligations, reserves for self-insurance, depreciation and amortization of property and equipment, amortization of intangible assets and future cash flows, fair values used to assess recoverability and impairment of long-lived assets, including goodwill, estimates of income taxes and the estimated effects of litigation and other contingencies. Reclassifications Certain reclassifications have been made to prior period amounts to conform to the current period financial statement presentation. The Company adopted a new accounting policy related to the classification of certain legal expenses. For matters related to ongoing operations, the Company continues to present legal expense as selling, general and administrative. For matters determined to be unrelated to ongoing operations, the Company classifies the legal expenses according to the nature of the underlying matter. The Company believes that this new accounting policy will more accurately present legal expenses on its consolidated statement of comprehensive loss. The adoption of this policy resulted in the recognition of approximately $5.4 million of legal expenses related to a certain legal settlement, which is included in Other, net on the consolidated statement of comprehensive loss for the year ended December 31, 2021. See Note 19 for additional information. Cash and Cash Equivalents and Short-Term Investment All highly liquid investments with an original maturity of three months or less are considered cash equivalents. The Company maintains its cash accounts in financial institutions that are insured by the Federal Deposit Insurance Corporation, with the exception of cash held by Sand Tiger in a Canadian financial institution. At December 31, 2021, we had $1.5 million, in Canadian dollars, of cash in Canadian accounts. Cash balances from time to time may exceed the insured amounts; however, the Company has not experienced any losses in such accounts and does not believe it is exposed to any significant credit risks on such accounts. The Company’s short-term investment consists of a certificate of deposit with a maturity over 90 days. Accounts Receivable Accounts receivable include amounts due from customers for services performed or goods sold. The Company grants credit to customers in the ordinary course of business and generally does not require collateral. Prior to granting credit to customers, the Company analyzes the potential customer’s risk profile by utilizing a credit report, analyzing macroeconomic factors and using its knowledge of the industry, among other factors. Most areas in the continental United States in which the Company operates provide for a mechanic’s lien against the property on which the service is performed if the lien is filed within the statutorily specified time frame. Customer balances are generally considered delinquent if unpaid by the 30th day following the invoice date and credit privileges may be revoked if balances remain unpaid. Interest on delinquent trade accounts receivable is recognized in other, net on the consolidated statement of comprehensive loss when chargeable and collectability is reasonably assured. During the period October 2017 through March 2019, the Company provided infrastructure services in Puerto Rico under master services agreements entered into by Cobra, one of the Company’s subsidiaries, with the Puerto Rico Electric Power Authority (“PREPA”) to perform repairs to PREPA’s electrical grid as a result of Hurricane Maria. During the years ended December 31, 2021, 2020 and 2019, the Company charged interest on delinquent trade accounts receivable pursuant to the terms of its agreements with PREPA totaling $36.6 million, $32.2 million and $42.0 million, respectively. These amounts are included in other, net on the consolidated statement of comprehensive loss. Included in “accounts receivable, net” on the condensed consolidated balance sheets as of December 31, 2021 and 2020 were interest charges of $110.8 million and $74.3 million, respectively. Allowance for Doubtful Accounts The Company regularly reviews receivables and provides for expected losses through an allowance for doubtful accounts. In evaluating the level of established reserves, the Company makes judgments regarding its customers’ ability to make required payments, economic events and other factors. As the financial condition of customers changes, circumstances develop, or additional information becomes available, adjustments to the allowance for doubtful accounts may be required. In the event the Company expects that a customer may not be able to make required payments, the Company would increase the allowance through a charge to income in the period in which that determination is made. If it is determined that previously reserved amounts are collectible, the Company would decrease the allowance through a credit to income in the period in which that determination is made. Uncollectible accounts receivable are periodically charged against the allowance for doubtful accounts once a final determination is made regarding their collectability. Following is a roll forward of the allowance for doubtful accounts for the years ended December 31, 2021, 2020 and 2019 (in thousands): Balance, January 1, 2019 $ 5,198 Additions charged to bad debt expense 1,771 Recoveries of receivables previously charged to bad debt expense (337) Deductions for uncollectible receivables written off (1,478) Balance, December 31, 2019 5,154 Additions charged to bad debt expense 22,705 Additions charged to other selling, general and administrative expense 3,950 Additions charged to other, net - related parties 1,427 Recoveries of receivables previously charged to bad debt expense (747) Deductions for uncollectible receivables written off (2,350) Balance, December 31, 2020 30,139 Additions charged to bad debt expense 41,873 Additions charged to revenue 27,071 Additions charged to other selling, general and administrative expense 273 Additions charged to other income (expense), net - related parties 515 Additions charged to other income (expense), net 1,474 Recoveries of receivables previously charged to bad debt expense (211) Deductions for uncollectible receivables written off (83,049) Balance, December 31, 2021 $ 18,085 The Company has made specific reserves consistent with Company policy which resulted in additions to allowance for doubtful accounts totaling $0.7 million, $3.3 million and $1.8 million, respectively, for the years ended December 31, 2021, 2020 and 2019. These additions were charged to bad debt expense based on the factors described above. Additionally, during the year ended December 31, 2021, the Company recorded additions to allowance for doubtful accounts of $0.3 million related to insurance claim receivables for its directors and officers liability policy. The Company will continue to pursue collection until such time as final determination is made consistent with Company policy. Gulfport The Company’s subsidiaries Stingray Pressure Pumping and Muskie were party to a pressure pumping contract and a sand supply contract, respectively, with Gulfport Energy Corporation (“Gulfport”). On November 13, 2020, Gulfport filed petitions for voluntary relief under chapter 11 of the Bankruptcy Code. Following is a roll forward of the allowance for doubtful accounts specifically related to Gulfport (in thousands): Balance, January 1, 2020 — Additions charged to bad debt expense 19,395 Additions charged to other selling, general and administrative expense 1,759 Additions charged to other, net - related parties 1,427 Balance, December 31, 2020 22,581 Additions charged to bad debt expense 41,196 Additions charged to revenue 27,070 Additions charged to other income (expense), net - related parties 1,842 Deductions for uncollectible receivables written off (80,975) Balance, December 31, 2021 $ 11,714 The Company had net accounts receivable due from Gulfport totaling $0.1 million as of December 31, 2021, which is included in “accounts receivable, net” on the consolidated balance sheets. See Notes 3 and 19 for additional information. PREPA As of December 31, 2021 and 2020, PREPA owed the Company $337.8 million and $301.2 million, respectively, which includes interest charged on delinquent balances. PREPA is currently subject to bankruptcy proceedings, which were filed in July 2017 and are currently pending in the U.S. District Court for the District of Puerto Rico. As a result, PREPA’s ability to meet its payment obligations is largely dependent upon funding from the Federal Emergency Management Agency (“FEMA”) or other sources. On September 30, 2019, Cobra filed a motion with the U.S. District Court for the District of Puerto Rico seeking recovery of the amounts owed to Cobra by PREPA, which motion was stayed by the Court. On March 25, 2020, Cobra filed an urgent motion to modify the stay order and allow the recovery of approximately $61.7 million in claims related to a tax gross-up provision contained in the emergency master service agreement, as amended, that was entered into with PREPA on October 19, 2017. This emergency motion was denied on June 3, 2020 and the Court extended the stay of our motion. On December 9, 2020, the Court again extended the stay of our motion and directed PREPA to file a status report by June 7, 2021. On April 6, 2021, Cobra filed a motion to lift the stay order. Following this filing, PREPA initiated discussion with Cobra, which resulted in PREPA and Cobra filing a joint motion to adjourn all deadlines relative to the April 6, 2021 motion until the June 16, 2021 omnibus hearing as a result of PREPA’s understanding that FEMA would be releasing a report in the near future relating to the emergency master service agreement between PREPA and Cobra that was executed on October 19, 2017. The joint motion was granted by the Court on April 14, 2021. On May 26, 2021, FEMA issued a Determination Memorandum related to the first contract between Cobra and PREPA in which, among other things, FEMA raised two contract compliance issues and, as a result, concluded that approximately $47 million in costs were not authorized costs under the contract. On June 14, 2021, the Court issued an order adjourning Cobra’s motion to lift the stay order to a hearing on August 4, 2021 and directing Cobra and PREPA to meet and confer in good faith concerning, among other things, (i) the May 26, 2021 Determination Memorandum issued by FEMA and (ii) whether and when a second determination memorandum is expected. The parties were further directed to file an additional status report, which was filed on July 20, 2021. On July 23, 2021, with the aid of Mammoth, PREPA filed an appeal of the entire $47 million that FEMA de-obligated in the May 26, 2021 Determination Memorandum. The appeal is currently pending. On August 4, 2021, the Court denied Cobra ’ s April 6, 2021 motion to lift the stay order, extended the stay of our motion seeking recovery of amounts owed to Cobra and directed the parties to file an additional joint status report, which was filed on January 22, 2022. On January 26, 2022, the Court extended the stay and directed the parties to file a further status report by July 25, 2022. The Company believes all amounts charged to PREPA, including interest charged on delinquent accounts receivable, were in accordance with the terms of the contracts. Further, there have been multiple reviews prepared by or on behalf of FEMA that have concluded that the amounts Cobra charged PREPA were reasonable, that PREPA adhered to Puerto Rican legal statutes regarding emergency situations, and that PREPA engaged in a reasonable procurement process. As noted above, in May 2021 FEMA raised two contract compliance issues and concluded that $47 million in costs were not eligible under the contract. PREPA, however, has filed an appeal of the entire $47 million, which is currently pending. The Company believes these receivables are collectible and for the reasons previously described as well as other factors, no allowance was deemed necessary at December 31, 2021 or 2020. However, in the event PREPA (i) does not have or does not obtain the funds necessary to satisfy its obligations to Cobra under the contracts, (ii) obtains the necessary funds but refuses to pay the amounts owed to the Company or (iii) otherwise does not pay amounts owed to the Company for services performed, the receivable may not be collectible. Inventory Inventory consists of raw sand and processed sand available for sale, raw materials, chemicals and other products sold as a bi-product of completion and production operations and supplies used in performing services. Inventory is stated at the lower of cost or market (net realizable value) on an average cost basis. The Company assesses the valuation of its inventories based upon specific usage, future utility, obsolescence and other factors. Inventory manufactured at the Company’s sand production facilities includes direct excavation costs, processing costs and overhead allocation. Stockpile tonnages are calculated by measuring the number of tons added and removed from the stockpile. Costs are calculated on a per ton basis and are applied to the stockpiles based on the number of tons in the stockpile. Inventory transported for sale at the Company’s terminal facility includes the cost of purchased or manufactured sand, plus transportation related charges. Coil tubing strings of various widths, diameters and lengths are included in inventory. The strings are used in providing specialized services to customers who are primarily operators of oil or gas wells and are used at various rates based on factors such as well conditions (i.e. pressure and friction), vertical and horizontal length of the well, running speed of the string in the well and total running feet accumulated to the string. The Company obtains usage information from data acquisition software and other established assessment methods and attempts to amortize the strings over their estimated useful life. In no event will a string be amortized over a period longer than 12 months. Amortization of coil strings is included in services cost of revenue in the consolidated statements of comprehensive loss and totaled $0.4 million and $1.6 million for the years ended December 31, 2020 and 2019, respectively. We did not recognize any amortization of coil strings for the year ended December 31, 2021. See Note 4 for additional disclosure related to inventory. Prepaid Expenses Prepaid expenses primarily consist of insurance costs and rail car freight and lease expense. These costs are expensed over the periods that they benefit. Property and Equipment Property and equipment, including renewals and betterments, are capitalized and stated at cost, while maintenance and repairs that do not increase the capacity, improve the efficiency or safety, or improve or extend the useful life are charged to operations as incurred. Disposals are removed at cost, less accumulated depreciation, and any resulting gain or loss is recorded in operations. Depreciation is calculated using the straight-line method over the shorter of the estimated useful life, or the remaining lease term, as applicable. Depreciation does not begin until property and equipment is placed in service. Once placed in service, depreciation on property and equipment continues while being repaired, refurbished, or between periods of deployment. Sand Reserves Sand reserve costs include engineering, mineralogical studies and other related costs to develop the mine, the removal of overburden to initially expose the mineral and building access ways. Exploration costs are expensed as incurred and classified as product cost of revenue. Capitalization of mine development project costs begins once the deposit is classified as proven and probable reserves. Drilling and related costs are capitalized for deposits where proven and probable reserves exist and the activities are directed at obtaining additional information on the deposit or converting non-reserve minerals to proven and probable reserves and the benefit is to be realized over a period greater than one year. Mining property and development costs are amortized using the units-of-production method on estimated measured tons in in-place reserves. The impact of revisions to reserve estimates is recognized on a prospective basis. Long-Lived Assets The Company reviews long-lived assets for recoverability in accordance with the provisions of Financial Accounting Standards Board (“FASB”) Accounting Standard Codification (“ASC”) 360, Impairment or Disposal of Long-Lived Assets , which requires that long-lived assets be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. Recoverability of assets is measured by comparing the carrying amount of an asset to future undiscounted net cash flows expected to be generated by the asset. These evaluations for impairment are significantly impacted by estimates of revenues, costs and expenses and other factors. If long-lived assets are considered to be impaired, the impairment to be recognized is measured by the amount in which the carrying amount of the assets exceeds the fair value of the assets. See Note 6 for additional disclosure related to impairment of long-lived assets. Goodwill Goodwill is tested for impairment annually, or more frequently if events or changes in circumstances indicate that goodwill might be impaired. If it is determined that an impairment exists, an impairment charge is recognized for the excess of carrying value over implied fair value. The fair value is determined using a combination of the income and market approaches. See Notes 6 and 7 for additional disclosures related to goodwill. Other Non-Current Assets Other non-current assets primarily consist of deferred financing costs on our credit facility (see Note 10), sales tax receivables and our equity method investment (see Note 8). Investments are accounted for under the equity method in circumstances where the Company has the ability to exercise significant influence over the operating and investing policies of the investee, but does not have control. Under the equity method, the Company recognizes its share of the investee’s earnings in its consolidated statements of comprehensive loss. Investments are evaluated for impairment and a charge to earnings is recognized when any identified impairment is determined to be other than temporary. Asset Retirement Obligations Mine reclamation costs, future remediation costs for inactive mines and other contractual site remediation costs are accrued based on management’s best estimate at the end of each period of the costs expected to be incurred at a site. Such cost estimates include, where applicable, ongoing care, maintenance and monitoring costs. Changes in estimates are reflected in earnings in the period an estimate is revised. Following is a roll forward of the Company’s asset retirement obligations for the years ended December 31, 2021 and 2020 (in thousands): December 31, 2021 2020 Balance as of beginning of period $ 4,746 $ 4,241 Additions and revisions of prior estimates (385) 372 Accretion expense 146 115 Liabilities settled (782) — Foreign currency translation adjustment (5) 18 Asset retirement obligation as of end of period $ 3,720 $ 4,746 Amortizable Intangible Assets Intangible assets subject to amortization include customer relationships and trade names. Customer relationships are amortized based on an estimated attrition factor and trade names are amortized over their estimated useful lives. See Notes 6 and 7 for additional disclosures related to intangible assets. Fair Value of Financial Instruments The Company’s financial instruments consist of cash and cash equivalents, short-term investments, trade receivables, trade payables, amounts receivable or payable to related parties and long-term debt. The carrying amount of cash and cash equivalents, trade receivables, trade payables and receivables and payables from related parties approximates fair value because of the short-term nature of the instruments. The fair value of long-term debt approximates it s carrying value because the cost of borrowing fluctuates based upon market conditions. Revenue Recognition The timing of revenue recognition may differ from contract billing or payment schedules, resulting in revenues that have been earned but not billed (“unbilled revenue”) or amounts that have been billed, but not earned (“deferred revenue”). The Company had $22.0 million and $32.3 million, respectively, of unbilled revenue included in accounts receivable, net in the consolidated balance sheets at December 31, 2021 and 2020. The Company had a nominal amount and $1.5 million, respectively, of unbilled revenue included in receivables from related parties, net in the consolidated balance sheets at December 31, 2021 and 2020. The Company had $3.2 million and $8.3 million, respectively, of deferred revenue included in accrued expenses and other current liabilities in the consolidated balance sheets at December 31, 2021 and 2020. Loss per Share Loss per share is computed by dividing net loss by the weighted average number of outstanding shares. See Note 15. Equity-based Compensation The Company measures equity-based payments at fair value on the date of grant and expenses the value of these equity-based payments in compensation expense over the applicable vesting periods. See Note 16. Stock-based Compensation The Company’s stock-based compensation program consists of restricted stock units granted to employees and restricted stock units granted to non-employee directors under the Mammoth Energy Services, Inc. 2016 Incentive Plan (the “2016 Plan”). The Company recognizes in its financial statements the cost of employee services received in exchange for restricted stock based on the fair value of the equity instruments as of the grant date. In general, this value is amortized over the vesting period; for grants with a non-substantive service condition, this value is recognized immediately. Amounts are recognized in cost of revenue and selling, general and administrative expenses. See Note 17. Income Taxes The Company’s operations are included in a consolidated federal income tax return and other state returns. Accordingly, the Company has recognized deferred tax assets and liabilities for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases for all our subsidiaries as if each entity were a corporation, regardless of its actual characterization for U.S. federal income tax purposes. Under FASB ASC 740, Income Taxes , deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using statutory tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of deferred tax assets and liabilities as a result of a change in tax rate are recognized in the period that includes the statutory enactment date. A valuation allowance for deferred tax assets is recognized when it is more likely than not that the benefit of deferred tax assets will not be realized. To assess that likelihood, the Company uses estimates and judgments regarding future taxable income, as well as the jurisdiction in which such taxable income is generated, to determine whether a valuation allowance is required. Certain income from our infrastructure services segment and income from our remote accommodations business is subject to foreign income taxes, and such taxes are provided in the financial statements pursuant to FASB ASC 740 . The Company evaluates tax positions taken or expected to be taken in preparation of its tax returns and disallows the recognition of tax positions that do not meet a “more likely than not” threshold of being sustained upon examination by the taxing authorities. The Company recorded an unrecognized tax benefit of $1.0 million during the year ended December 31, 2021 related to the 2020 tax year returns in Puerto Rico. No uncertain tax positions existed at December 31, 2020. It is the Company’s policy to recognize interest and applicable penalties related to uncertain tax positions in income tax expense. Litigation and Contingencies Accruals for litigation and contingencies are reflected in the consolidated financial statements based on management’s assessment, including advice of legal counsel, of the expected outcome of litigation or other dispute resolution proceedings and/or the expected resolution of contingencies. Liabilities for estimated losses are accrued if the potential loss from any claim or legal proceeding is considered probable and the amount can be reasonably estimated. Significant judgment is required in both the determination of probability of loss and the determination as to whether the amount is reasonably estimable. Accruals are based only on information available at the time of the assessment due to the uncertain nature of such matters. As additional information becomes available, management reassesses potential liabilities related to pending claims and litigation and may revise its previous estimates. Foreign Currency Translation For foreign operations, assets and liabilities are translated at the period-end exchange rate and income statement items are translated at the average exchange rate for the period. Resulting translation adjustments are recorded within accumulated other comprehensive loss. Assets and liabilities denominated in foreign currencies, if any, are re-measured at the balance sheet date. Transaction gains or losses are included as a component of current period earnings. Environmental Matters The Company is subject to various federal, state and local laws and regulations relating to the protection of the environment. Management has established procedures for the ongoing evaluation of the Company’s operations, to identify potential environmental exposures and to comply with regulatory policies and procedures. Environmental expenditures that relate to current operations are expensed or capitalized as appropriate. Expenditures that relate to an existing condition caused by past operations and do not contribute to current or future revenue generation are expensed as incurred. Liabilities are recorded when environmental costs are probable and the costs can be reasonably estimated. The Company maintains insurance which may cover in whole or in part certain environmental expenditures. As of December 31, 2021 and 2020, there were no probable environmental matters. Other Comprehensive Loss Comprehensive loss consists of net loss and other comprehensive loss. Other comprehensive loss included certain changes in equity that are excluded from net loss. Specifically, cumulative foreign currency translation adjustments are included in accumulated other comprehensive loss. Concentrations of Credit Risk and Significant Customers Financial instruments that potentially subject the Company to concentrations of credit risk consist of cash and cash equivalents in excess of federally insured limits and trade receivables. Following is a summary of our significant customers based on accounts receivable balances at December 31, 2021 and 2020 and revenues derived for the years ended December 31, 2021, 2020 and 2019: REVENUES ACCOUNTS RECEIVABLE Years Ended December 31, At December 31, 2021 2020 2019 2021 2020 Customer A (a) — % — % 15 % 83 % 71 % Customer B (b) 7 % 16 % 20 % — % 7 % Customer C (c) 3 % 15 % — % — % 6 % a. Customer A is a third-party customer. Revenues and the related accounts receivable balances earned from Customer A were derived from the Company’s infrastructure services segment. Accounts receivable for Customer A also includes receivables due for interest charged on delinquent accounts receivable. b. Customer B was a related-party customer until June 29, 2021. Revenues earned from this customer prior to June 29, 2021 are included in services revenue - related parties and product revenue - related parties on the consolidated statements of comprehensive loss. The related accounts receivable are included in accounts receivable, net on the consolidated balance sheet at December 31, 2021 and receivables due from related parties, net at December 31, 2020. Revenues and the related accounts receivable balances earned from Customer B were derived from the Company’s well completion services segment, natural sand proppant services segment and other businesses. Accounts receivable for Customer B also included receivables due for interest charged on delinquent accounts receivable. c. Customer C is a third-party customer. Revenues and the related accounts receivable balances earned from Customer C were derived from the Company’s infrastructure services segment. Recent Accounting Pronouncements Accounting Pronouncements Recently Adopted In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02 “Leases (Topic 842)” amending the current accounting for leases. Under the new provisions, all lessees will report a right of use asset and lease liability on the balance sheet for all leases with a term longer than one year, while maintaining substantially similar classifications for financing and operating leases. Lessor accounting remains substantially unchanged with the exception that no leases entered into after the effective date will be classified as leveraged leases. ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, and interim periods within that fiscal year. The Company adopted this ASU effective January 1, 2019 utilizing the transition method permitted by ASU No. 2018-11 “Leases (Topic 842): Targeted Improvements”, issued in August 2018, which permits an entity to recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption with no adjustment made to the comparative periods presented in the consolidated financial statements. See Note 14 for the impact the adoption of this standard had on the Company’s financial statements. In June 2018, the FASB issued ASU No. 2018-07, “Compensation - Stock Compensation (Topic 718): Improvements to Non-employee Share-Based Accounting,” which simplifies the accounting for share-based payments granted to non-employees by aligning the accounting with requirements for employee share-based compensation. Upon transition, this ASU requires non-employee awards to be measured at fair value as of the adoption date. This ASU is effective for fiscal years beginning after December 15, 2018, and interim periods within that fiscal year. The Company adopted this ASU effective January 1, 2019 and estimates the fair value of its non-employee awards (see Note 16) was approximately $18.9 million as of thi |
Revenues
Revenues | 12 Months Ended |
Dec. 31, 2021 | |
Revenue from Contract with Customer [Abstract] | |
Revenues | RevenuesThe Company’s primary revenue streams include infrastructure services, well completion services, natural sand proppant services, drilling services and other services, which includes coil tubing, pressure control, flowback, cementing, acidizing, equipment rentals, full service transportation, crude oil hauling, remote accommodations and equipment manufacturing. See Note 20 for the Company’s revenue disaggregated by type. Certain of the Company’s customer contracts include provisions entitling the Company to a termination penalty when the customer invokes its contractual right to terminate prior to the contract’s nominal end date. The termination penalties in the customer contracts vary, but are generally considered substantive for accounting purposes and create enforceable rights and obligations throughout the stated duration of the contract. The Company accounts for a contract cancellation as a contract modification in the period in which the customer invokes the termination provision. The determination of the contract termination penalty is based on the terms stated in the related customer agreement. As of the modification date, the Company updates its estimate of the transaction price using the expected value method, subject to constraints, and recognizes the amount over the remaining performance period. Infrastructure Services Infrastructure services are typically provided pursuant to master service agreements, repair and maintenance contracts or fixed price and non-fixed price installation contracts. Pricing under these contracts may be unit priced, cost-plus/hourly (or time and materials basis) or fixed price (or lump sum basis). Generally, the Company accounts for infrastructure services as a single performance obligation satisfied over time. In certain circumstances, the Company supplies materials that are utilized during the jobs as part of the agreement with the customer. The Company accounts for these infrastructure agreements as multiple performance obligations satisfied over time. Revenue is recognized over time as work progresses based on the days completed or as the contract is completed. Under certain customer contracts in our infrastructure services segment, the Company warranties equipment and labor performed for a specified period following substantial completion of the work. Well Completion Services Well completion services are typically provided based upon a purchase order, contract or on a spot market basis. Services are provided on a day rate, contracted or hourly basis. Generally, the Company accounts for well completion services as a single performance obligation satisfied over time. In certain circumstances, the Company supplies proppant that is utilized for pressure pumping as part of the agreement with the customer. The Company accounts for these pressure pumping agreements as multiple performance obligations satisfied over time. Jobs for these services are typically short-term in nature and range from a few hours to multiple days. Generally, revenue is recognized over time upon the completion of each segment of work based upon a completed field ticket, which includes the charges for the services performed, mobilization of the equipment to the location and personnel. Pursuant to a contract with Gulfport, Stingray Pressure Pumping agreed to provide Gulfport with use of up to two pressure pumping fleets for the period covered by the contract. Under this agreement, performance obligations were satisfied as services were rendered based on the passage of time rather than the completion of each segment of work. Stingray Pressure Pumping had the right to receive consideration from this customer even if circumstances prevent us from performing work. All consideration owed to Stingray Pressure Pumping for services performed during the contractual period is fixed and the right to receive it is unconditional. On December 28, 2019, Gulfport filed a legal action in Delaware state court seeking the termination of this contract and monetary damages. Further, on November 13, 2020, Gulfport filed petitions for voluntary relief under chapter 11 of the Bankruptcy Code. On March 22, 2021, Gulfport listed the Stingray Pressure Pumping contract on its master rejection schedule filed with the bankruptcy court. The Company determined that these factors changed the scope of the contract, accelerated the duration of, and otherwise changed the rights and obligations of each party to the contract. As a result, the Company accounted for this as a contract modification during the three months ended March 31, 2021. Stingray Pressure Pumping used the expected value method to estimate unliquidated damages totaling $37.9 million, which resulted in the recognition of net revenue totaling $14.8 million and bad debt expense of $2.9 million on previously recognized revenue during the three months ended March 31, 2021. On September 21, 2021, the Company and Gulfport reached a settlement under which all litigation relating to the Stingray Pressure Pumping contract will be terminated. Stingray Pressure Pumping released all claims against Gulfport and its subsidiaries with respect to Gulfport’s bankruptcy proceedings and each of the parties released all claims they had against the others with respect to the litigation matters discussed in Note 19. As a result of this settlement agreement, during the three months ended September 30, 2021, the Company wrote off its remaining receivable related to the Stingray Pressure Pumping claim resulting in bad debt expense and other expense of $31.0 million and $1.3 million, respectively. Gulfport was a related party until June 29, 2021. On June 29, 2021, pursuant to the terms of its plan of reorganization, all of the Company’s shares that Gulfport owned were transferred to a trust for the benefit of certain of Gulfport’s creditors. The revenue recognized related to this agreement is included in “services revenue - related parties” in the accompanying consolidated statement of comprehensive loss and the related accounts receivable is included in “receivables due from related parties” as of December 31, 2020. See Notes 12 and 19 below. Additional revenue is generated through labor charges and the sale of consumable supplies that are incidental to the service being performed. Such amounts are recognized ratably over the period during which the corresponding goods and services are consumed. Natural Sand Proppant Services The Company sells natural sand proppant through sand supply agreements with its customers. Under these agreements, sand is typically sold at a flat rate per ton or a flat rate per ton with an index-based adjustment. The Company recognizes revenue at the point in time when the customer obtains legal title to the product, which may occur at the production facility, rail origin or at the destination terminal. Certain of the Company’s sand supply agreements contain a minimum volume commitment related to sand purchases whereby the Company charges a shortfall payment if the customer fails to meet the required minimum volume commitment. These agreements may also contain make-up provisions whereby shortfall payments can be applied in future periods against purchased volumes exceeding the minimum volume commitment. If a make-up right exists, the Company has future performance obligations to deliver excess volumes of product in subsequent periods. In accordance with ASC 606, if the customer fails to meet the minimum volume commitment, the Company will assess whether it expects the customer to fulfill its unmet commitment during the contractually specified make-up period based on discussions with the customer and management’s knowledge of the business. If the Company expects the customer will make-up deficient volumes in future periods, revenue related to shortfall payments will be deferred and recognized on the earlier of the date on which the customer utilizes make-up volumes or the likelihood that the customer will exercise its right to make-up deficient volumes becomes remote. As of December 31, 2021 and 2020, the Company had deferred revenue totaling $3.0 million and $7.9 million, respectively, related to shortfall payments. These amounts are included in accrued expenses and other current liabilities on the consolidated balance sheet. If the Company does not expect the customer will make-up deficient volumes in future periods, the breakage model will be applied and revenue related to shortfall payments will be recognized when the model indicates the customer’s inability to take delivery of excess volumes. During the years ended December 31, 2021, 2020 and 2019, the Company recognized revenue totaling $12.0 million, $24.8 million and $2.8 million, respectively, related to shortfall payments. In certain of the Company’s sand supply agreements, the customer obtains control of the product when it is loaded into rail cars and the customer reimburses the Company for all freight charges incurred. The Company has elected to account for shipping and handling as activities to fulfill the promise to transfer the sand. If revenue is recognized for the related product before the shipping and handling activities occur, the Company accrues the related costs of those shipping and handling activities. Pursuant to its contract with Gulfport, Muskie has agreed to sell and deliver specified amounts of sand to Gulfport. In September 2020, Muskie filed a lawsuit against Gulfport to recover delinquent payments due under this agreement. On November 13, 2020, Gulfport filed petitions for voluntary relief under chapter 11 of the Bankruptcy Code. On March 22, 2021, Gulfport listed the Muskie contract on its master rejection schedule filed with the bankruptcy court. The Company determined that these factors changed the scope of the contract, accelerated the duration of, and otherwise changed the rights and obligations of each party to the contract. As a result, the Company accounted for this as a contract modification during the three months ended March 31, 2021. Muskie used the expected value method to estimate unliquidated damages totaling $8.5 million, which resulted in the recognition of net revenue totaling $2.1 million and bad debt expense of $1.0 million on previously recognized revenue during the three months ended March 31, 2021. On September 21, 2021, the Company and Gulfport reached a settlement under which all litigation relating to the Muskie contract was terminated, each of the parties released all claims they had against the others with respect to the litigation matters discussed in Note 19 and Muskie’s contract claim against Gulfport was allowed under Gulfport’s plan of reorganization in the amount of $3.1 million. As a result of this settlement agreement, Muskie recognized bad debt expense of $0.2 million during the third quarter of 2021. As of December 31, 2021, Muskie had net accounts receivable due from Gulfport totaling $0.1 million, which includes a nominal amount of interest on delinquent accounts receivable. Gulfport was a related party until June 29, 2021. The revenue recognized related to this agreement is included in “product revenue - related parties” in the accompanying consolidated statement of comprehensive loss and the related accounts receivable is included in “accounts receivable, net” in the consolidated balance sheets as of December 31, 2021 and “receivables due from related parties” as of December 31, 2020. See Notes 12 and 19 below. Drilling Services Contract drilling services were provided under daywork contracts. Directional drilling services, including motor rentals, are provided on a day rate or hourly basis, and revenue is recognized as work progresses. Performance obligations are satisfied over time as the work progresses based on the measure of output. Mobilization revenue and costs were recognized over the days of actual drilling. As a result of market conditions, the Company temporarily shut down its contract land drilling operations beginning in December 2019 and its rig moving operations beginning in April 2020. Other Services During the periods presented, the Company also provided aviation, coil tubing, pressure control, flowback, cementing, acidizing, equipment rentals, crude oil hauling, full service transportation, remote accommodations and equipment manufacturing, which are reported under other services. As a result of market conditions, the Company temporarily shut down its cementing and acidizing operations as well as its flowback operations beginning in July 2019, its coil tubing, pressure control and full service transportation operations beginning in July 2020 and its crude oil hauling operations beginning in July 2021. The Company’s other services are typically provided based upon a purchase order, contract or on a spot market basis. Services are provided on a day rate, contracted or hourly basis. Performance obligations for these services are satisfied over time and revenue is recognized as the work progresses based on the measure of output. Jobs for these services are typically short-term in nature and range from a few hours to multiple days. Practical Expedients The Company does not disclose the value of unsatisfied performance obligations for (i) contracts with an original expected length of one year or less and (ii) contracts in which variable consideration is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied distinct good or service that forms part of a single performance obligation. Contract Balances Following is a rollforward of the Company’s contract liabilities (in thousands): Balance, January 1, 2019 $ 4,304 Deduction for recognition of revenue (4,827) Increase for deferral of shortfall payments 8,442 Increase for deferral of customer prepayments 675 Deduction of shortfall payments due to contract renegotiations (1,350) Balance, December 31, 2019 7,244 Deduction for recognition of revenue (25,047) Increase for deferral of shortfall payments 25,436 Increase for deferral of customer prepayments 648 Balance, December 31, 2020 8,281 Deduction for recognition of revenue (12,329) Increase for deferral of shortfall payments 7,023 Increase for deferral of customer prepayments 275 Balance, December 31, 2021 $ 3,250 The Company did not have any contract assets as of December 31, 2021, December 31, 2020 or December 31, 2019. Performance Obligations Revenue recognized in the current period from performance obligations satisfied in previous periods was a nominal amount for the years ended December 31, 2021, 2020 and 2019. As of December 31, 2021, the Company had unsatisfied performance obligations totaling $1.7 million, which will be recognized over the next 6 months. |
Inventories
Inventories | 12 Months Ended |
Dec. 31, 2021 | |
Inventory Disclosure [Abstract] | |
Inventories | Inventories Inventories consist of raw sand and processed sand available for sale, chemicals and other products sold as a bi-product of completion and production operations and supplies used in performing services. Inventory is stated at the lower of cost or net realizable value on an average cost basis. The Company assesses the valuation of its inventories based upon specific usage, future utility, obsolescence and other factors. A summary of the Company’s inventories is shown below (in thousands): December 31, 2021 2020 Supplies $ 4,557 $ 6,312 Raw materials 701 613 Work in process 2,435 3,478 Finished goods 673 1,617 Total inventory $ 8,366 $ 12,020 |
Property, Plant and Equipment
Property, Plant and Equipment | 12 Months Ended |
Dec. 31, 2021 | |
Property, Plant and Equipment [Abstract] | |
Property, Plant and Equipment | Property, Plant and Equipment Property, plant and equipment include the following (in thousands): December 31, Useful Life 2021 2020 Pressure pumping equipment 3-5 years $ 220,414 $ 217,945 Drilling rigs and related equipment 3-15 years 111,478 113,146 Machinery and equipment 7-20 years 166,873 172,272 Buildings (a) 15-39 years 46,006 48,776 Vehicles, trucks and trailers 5-10 years 103,982 111,911 Coil tubing equipment 4-10 years 7,592 8,541 Land N/A 13,417 13,417 Land improvements 15 years or life of lease 10,133 10,133 Rail improvements 10-20 years 13,793 13,793 Other property and equipment (b) 3-12 years 18,235 18,640 711,923 728,574 Deposits on equipment and equipment in process of assembly (c) 3,300 3,191 715,223 731,765 Less: accumulated depreciation (d) 538,637 480,503 Total property, plant and equipment, net $ 176,586 $ 251,262 a. Included in Buildings at each of December 31, 2021 and 2020 are costs of $7.6 million related to assets under operating leases. b. Included in Other property and equipment at each of December 31, 2021 and 2020 are costs of $6.0 million related to assets under operating leases. c. Deposits on equipment and equipment in process of assembly represents deposits placed with vendors for equipment that is in the process of assembly and purchased equipment that is being outfitted for its intended use. The equipment is not yet placed in service. d. Includes accumulated depreciation of $6.6 million and $5.0 million at December 31, 2021 and 2020, respectively, related to assets under operating leases. Proceeds from customers for horizontal and directional drilling services equipment, damaged or lost down-hole are reflected in revenue with the carrying value of the related equipment charged to cost of service revenues and are reported as cash inflows from investing activities in the statement of cash flows. For the years ended December 31, 2021, 2020 and 2019, proceeds from the sale of equipment damaged or lost down-hole were $0.3 million, $0.7 million, and a nominal amount, respectively, and gain on sales of equipment damaged or lost down-hole were $0.3 million, $0.7 million, and a nominal amount, respectively. Proceeds from assets sold or disposed of as well as the carrying value of the related equipment are reflected in other, net on the consolidated statement of comprehensive loss. For the years ended December 31, 2021, 2020 and 2019, proceeds from the sale of equipment were $11.2 million, $6.1 million and $3.2 million, respectively, and gains (losses) from the sale or disposal of equipment were $5.1 million, $0.7 million and ($0.1) million, respectively. A summary of depreciation, depletion, amortization and accretion expense is shown below (in thousands): Years Ended December 31, 2021 2020 2019 Depreciation expense $ 76,093 $ 93,332 $ 112,435 Accretion and depletion expense 1,381 970 3,477 Amortization expense 1,001 1,015 1,121 Depreciation, depletion, amortization and accretion $ 78,475 $ 95,317 $ 117,033 |
Impairments
Impairments | 12 Months Ended |
Dec. 31, 2020 | |
Property, Plant and Equipment [Abstract] | |
Impairments | Impairments Impairment of Goodwill Under GAAP, the Company has the option to first assess qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of one or more of its reporting units is greater than its carrying amount. If, after assessing the totality of events or circumstances, the Company determines it is more likely than not that the fair value of a reporting unit is greater than its carrying amount, there is no need to perform any further testing. However, if the Company concludes otherwise, then it is required to perform a quantitative impairment test by calculating the fair value of the reporting unit and comparing the fair value with the carrying amount of the reporting unit. If the fair value of the reporting unit is less than its carrying value, an impairment loss is recorded based on that difference. The Company performed the qualitative assessment described above during the fourth quarter of 2021. Based on this assessment, the Company concluded that it was more likely than not that the fair value of the Stingray Pressure Pumping, Silverback and Aviation reporting units was greater than their carrying value. Accordingly, no further testing was required on these units. Additionally, the Company concluded that the carrying value for its infrastructure reporting unit was greater than its fair value. To determine fair value of the infrastructure reporting unit at December 31, 2021, the Company used the income approach. The income approach estimates the fair value based on anticipated cash flows that are discounted using a weighted average cost of capital. As a result, the Company impaired goodwill associated with 5 Star and Higher Power, resulting in a $0.9 million impairment charge for 2021. Oil prices declined significantly in March 2020 as a result of geopolitical events that increased the supply of oil in the market as well as effects of the COVID-19 pandemic. As a result, the Company determined that it was more likely than not that the fair value of certain of its reporting units were less than their carrying value. Therefore, the Company performed an interim goodwill impairment test. The Company impaired goodwill associated with Stingray Pressure Pumping, Silverback and WTL, resulting in a $55.0 million impairment charge during the first quarter of 2020. The Company performed an assessment of goodwill during the fourth quarter of 2020 and determined that the fair value of its goodwill was greater than its carrying value. Therefore, no additional impairment was necessary at December 31, 2020. To determine fair value, the Company used a combination of the income and market approaches. The income approach estimates the fair value based on anticipated cash flows that are discounted using a weighted average cost of capital. The market approach estimates the fair value using comparative multiples, which involves significant judgment in the selection of the appropriate peer group companies and valuation multiples. The Company performed its annual assessment of goodwill during the fourth quarter of 2019 and determined that the carrying value of goodwill for certain of its entities was greater than their fair values. As a result, the Company impaired goodwill associated with Stingray Pressure Pumping, SR Energy, Taylor Frac and Cobra Aviation, resulting in a $30.5 million impairment charge in 2019. To determine fair value at December 31, 2019, the Company used a combination of the income and market approaches. The income approach estimates the fair value based on anticipated cash flows that are discounted using a weighted average cost of capital. The market approach estimates the fair value using comparative multiples, which involves significant judgment in the selection of the appropriate peer group companies and valuation multiples. Additionally, during the third quarter of 2019, the Company temporarily shut down its cementing and acidizing operations. As a result, the Company recognized goodwill impairment expense of $3.2 million associated with Cementing and Stingray Cementing and Acidizing. The fair value was measured using an income approach. Impairment of Other Long-Lived Assets A summary of impairment of other long-lived assets is as follows (in thousands): December 31, 2021 2020 2019 Water transfer equipment $ — $ 4,203 $ — Crude oil hauling equipment — 3,275 — Coil tubing equipment — 2,160 — Flowback equipment — 1,514 — Rental equipment — 1,308 — Drilling rigs and related equipment — — 2,955 Other property, plant and equipment — 437 3,557 Intangible assets 1,212 — 846 $ 1,212 $ 12,897 $ 7,358 Due to market conditions, the Company has temporarily shut down its crude oil hauling operations beginning in July 2021. As a result, the Company recognized impairment of trade names totaling $0.5 million, which is included in impairment of other long-lived assets on the consolidated statements of comprehensive loss. The Company performed a review of its intangible asset balances as of December 31, 2021 and determined the fair value of Higher Power’s trade names and customer relationships was less than their carrying value, resulting in an additional impairment expense of $0.7 million at year-end. Oil prices declined significantly in March 2020 as a result of geopolitical events that increased the supply of oil in the market as well as effects of the COVID-19 pandemic. As a result, the Company determined that it was more likely than not that the fair value of certain of its oilfield services assets were less than their carrying value. Therefore, the Company performed an interim impairment test. As a result of the test, the Company recorded impairments totaling $12.9 million to its fixed assets during the first quarter of 2020. The Company measured the fair values of these assets using direct and indirect observable inputs (Level 2) based on a market approach. For the year ended December 31, 2019, the Company recognized impairments related to drilling rig assets and other property, plant and equipment of $3.0 million and $3.6 million, respectively. These assets were deemed impaired based on future expected cash flows of the equipment. The Company measured the fair value of its drilling rig assets at December 31, 2019 using direct and indirect observable inputs (Level 2) based on a market approach. The Company measured the fair values of its other property, plant and equipment at December 31, 2019 using direct and indirect observable inputs (Level 2) based on a market approach. The Company determined the fair value of WTL’s non-contractual customer relationships was less than their carrying value, resulting in impairment expense of $0.8 million during the year ended December 31, 2019. Additionally, during the third quarter of 2019, the Company temporarily shut down its flowback operations, resulting in impairment of non-contractual customer relationships of $0.1 million. The assumptions used in the impairment evaluation for long-lived assets are inherently uncertain and require management’s judgment. A continued period of low oil and natural gas prices or continued reductions in capital expenditures by our customers would likely have an adverse impact on our utilization and the prices that we receive for our services. This could result in the recognition of future material impairment charges on the same, or additional, property and equipment if future cash flow estimates, based upon information then available to management, indicate that their carrying values are not recoverable. |
Goodwill and Intangible Assets
Goodwill and Intangible Assets | 12 Months Ended |
Dec. 31, 2021 | |
Goodwill and Intangible Assets Disclosure [Abstract] | |
Goodwill and Intangible Assets | Goodwill and Intangible Assets Goodwill Changes in the net carrying amount of goodwill by reporting segment (see Note 20) for the years ended December 31, 2021 and 2020 are presented below (in thousands): Infrastructure Well Completion Sand Other Total Balance as of January 1, 2020 Goodwill $ 891 $ 86,043 $ 2,684 $ 14,830 $ 104,448 Accumulated impairment losses — (23,423) (2,684) (10,760) (36,867) 891 62,620 — 4,070 67,581 Acquisitions — — — — — Impairment losses (a) — (53,406) — (1,567) (54,973) Balance as of December 31, 2020 Goodwill 891 86,043 2,684 14,830 104,448 Accumulated impairment losses — (76,829) (2,684) (12,327) (91,840) 891 9,214 — 2,503 12,608 Acquisitions — — — — — Impairment losses (a) (891) — — — (891) Balance as of December 31, 2021 Goodwill 891 86,043 2,684 14,830 104,448 Accumulated impairment losses (891) (76,829) (2,684) (12,327) (92,731) $ — $ 9,214 $ — $ 2,503 $ 11,717 a. See Note 6 for a description of impairment losses recognized. Intangible Assets The Company had the following definite lived intangible assets recorded as of the dates presented below (in thousands): December 31, 2021 2020 Customer relationships $ — $ 1,050 Trade names 7,850 9,063 Less: accumulated amortization - customer relationships — (642) Less: accumulated amortization - trade names (5,289) (4,697) Intangible assets, net $ 2,561 $ 4,774 Amortization expense for intangible assets was $1.0 million, $1.0 million and $1.1 million for the years ended December 31, 2021, 2020 and 2019, respectively. The Company recognized impairment of intangible assets totaling $1.2 million and $0.8 million, respectively, for the years ended December 31, 2021 and 2019. See Note 6 for a description of these impairment losses. The original lives of trade names range from 10 to 20 years and as of December 31, 2021 the remaining average useful life was 3.95 years. Aggregated expected amortization expense for the future periods is expected to be as follows (in thousands): Year ended December 31: Amount 2022 $ 779 2023 779 2024 710 2025 91 2026 91 Thereafter 111 $ 2,561 |
Equity Method Investment
Equity Method Investment | 12 Months Ended |
Dec. 31, 2021 | |
Equity Method Investments and Joint Ventures [Abstract] | |
Equity Method Investment | Equity Method Investment On December 21, 2018, Cobra Aviation and Wexford Partners Investment Co. LLC (“Wexford Investment”), a related party, formed a joint venture under the name of Brim Acquisitions LLC (“Brim Acquisitions”) to acquire all outstanding equity interest in Brim Equipment for a total purchase price of approximately $2.0 million. Cobra Aviation owns a 49% economic interest and Wexford Investment owns a 51% economic interest in Brim Acquisitions, and each member contributed its pro rata portion of Brim Acquisitions initial capital of $2.0 million. Brim Acquisitions, through Brim Equipment, owns four commercial helicopters and leases five commercial helicopters for operations, which it uses to provide a variety of services, including short haul, aerial ignition, hoist operations, aerial photography, fire suppression, construction services, animal/capture/survey, search and rescue, airborne law enforcement, power line construction, precision long line operations, pipeline construction and survey, mineral and seismic exploration, and aerial seeding and fertilization. The Company uses the equity method of accounting to account for its investment in Brim Acquisitions, which had a carrying value of approximately $3.4 million and $3.7 million, respectively, at December 31, 2021 and 2020. The investment is included in other non-current assets on the consolidated balance sheets. The Company recorded equity method adjustments to its investment for its share of Brim Acquisitions’ (loss) income of ($0.3) million, $0.6 million, and $1.0 million respectively, for the years ended December 31, 2021, 2020 and 2019, respectively, which is included in other, net on the consolidated statements of comprehensive loss. The Company made additional investments totaling $0.5 million and $0.7 million during the years ended December 31, 2020 and 2019, respectively. No additional investments were made during the year ended December 31, 2021. |
Accrued Expenses and Other Curr
Accrued Expenses and Other Current Liabilities and Other Long-Term Liabilities | 12 Months Ended |
Dec. 31, 2021 | |
Payables and Accruals [Abstract] | |
Accrued Expenses and Other Current Liabilities and Other Long-Term Liabilities | Accrued Expenses and Other Current Liabilities and Other Long-Term Liabilities Accrued expense and other current liabilities and Other long-term liabilities included the following (in thousands): December 31, 2021 2020 Accrued Expenses and Other Current Liabilities Accrued legal settlement (a) $ 18,966 $ — State and local taxes payable 13,772 13,838 Financed insurance premiums (b) 9,852 10,394 Deferred revenue 3,250 8,281 Accrued compensation and benefits 5,133 3,710 Insurance reserves 1,413 1,941 Payroll tax liability 2,810 1,816 Financing leases 1,834 1,499 Sale-leaseback liability (c) 3,340 1,290 Other 2,146 1,639 Total accrued expenses and other current liabilities $ 62,516 $ 44,408 Other Long-Term Liabilities Financing leases $ 4,375 4,618 Sale-leaseback liability (c) 7,318 3,348 Payroll tax liability — 1,977 Other — 492 Total other long-term liabilities $ 11,693 $ 10,435 a. In June 2021, the Company reached an agreement to settle a certain legal matter. See Note 19 for additional detail. b. Financed insurance premiums are due in monthly installments, are unsecured and mature within the twelve-month period following the close of the year. As of December 31, 2021, the applicable interest rates associated with financed insurance premiums ranged from 1.95% to 2.45%. As of December 31, 2020, the applicable interest rates associated with financed insurance premiums ranged from 3.45% to 3.75%. |
Debt
Debt | 12 Months Ended |
Dec. 31, 2021 | |
Debt Disclosure [Abstract] | |
Debt | Debt Long-term debt included the following (in thousands): December 31, 2021 2020 Revolving credit facility 83,370 78,000 Aviation note 3,371 4,551 Unamortized debt issuance costs (33) (48) Total debt 86,708 82,503 Less: current portion 1,468 1,165 Total long-term debt $ 85,240 $ 81,338 Mammoth Credit Facility On October 19, 2018, Mammoth Inc. and certain of its direct and indirect subsidiaries, as borrowers, entered into an amended and restated revolving credit and security agreement with the lenders party thereto and PNC Bank, National Association, as a lender and as administrative agent for the lenders, as amended and restated (the “revolving credit facility”). The revolving credit facility matures on October 19, 2023. Borrowings under the revolving credit facility are secured by the assets of Mammoth Inc., inclusive of the subsidiary companies, and are subject to a borrowing base calculation prepared monthly. The revolving credit facility also contains various customary affirmative and restrictive covenants. Among the covenants is a financial covenant, including a minimum fixed charges coverage ratio of at least 1.1 to 1.0. As a result of the lack of payment from PREPA, the Company projected that it would likely breach the leverage ratio covenant contained in its revolving credit facility for the fiscal quarter ended September 30, 2021. On November 3, 2021, the Company entered into a third amendment to its revolving credit facility (the “Third Amendment”) to, among other things, (i) suspend the leverage ratio and fixed charges coverage ratio covenants for the quarters ending September 30, 2021 and December 31, 2021, (ii) permanently reduce the maximum revolving advance amount from $130 million to $120 million, (iii) add a minimum adjusted EBITDA financial covenant of $6.0 million for the quarter ending December 31, 2021, (iv) set the applicable margin on all loans at 3.50% during the limited covenant waiver period, (v) add a requirement to maintain revolver availability of not less than $10.0 million at all times during the limited covenant waiver period, (vi) permanently reduce the maximum revolving advance amount in an amount equal to fifty percent (50%) of any mandatory prepayments made with non-recurring proceeds that are received during the limited covenant waiver period, and (vii) eliminate the declaration of unrestricted subsidiaries during the limited covenant waiver period. The limited covenant waiver period commenced on the effective date of the Third Amendment and was scheduled to end on the earlier to occur of (i) May 15, 2022, (ii) the Company reporting compliance with both the leverage ratio and the fixed charge coverage ratio covenants for either its fiscal quarter ending September 30, 2021 or December 31, 2021, and (iii) the occurrence of any event of default after the effective date of the Third Amendment. Under the Third Amendment, the Company also agreed to engage an advisor during the limited covenant waiver period to advise the Company and its subsidiaries with regard to, among other things, efforts to achieve certain operation efficiencies, improvement in results of operations, and general business strategy, and provide assistance to the Company and its subsidiaries in the preparation of the supplemental reporting and information required by the Third Amendment. At December 31, 2021, there were outstanding borrowings under the revolving credit facility of $83.4 million and $16.5 million of available borrowing capacity, after giving effect to $9.0 million of outstanding letters of credit and the requirement to maintain a $10 million reserve out of the available borrowing capacity during the limited waiver period. At December 31, 2020, there were outstanding borrowings under the revolving credit facility of $78.0 million and $38.7 million of borrowing capacity under the facility, after giving effect to $13.0 million of outstanding letters of credit. As of December 31, 2021, the Company was in compliance with its financial covenants under the revolving credit facility, as amended and waived by the Third Amendment. On February 28, 2022, the Company entered into a fourth amendment to the revolving credit facility (the “Fourth Amendment”) to, among other things, (i) amend the financial covenants as outlined below, (ii) provide for a conditional increase of the applicable interest margin, (iii) permit certain sale-leaseback transactions, (iv) provide for a reduction in the maximum revolving advance amount in an amount equal to 50% of the PREPA claims proceeds, subject to a floor equal to the sum of eligible billed and unbilled accounts receivables, and (v) classifies the payments pursuant to the Company ’ s settlement agreement with MasTec Renewables Puerto Rico, LLC (“MasTec”) as restricted payments and requires $20.0 million of availability both before and after making such payments. The financial covenants under our revolving credit facility were amended as follows: • the leverage ratio was eliminated; • the fixed charge coverage ratio was reduced to .85 to 1.0 for the six months ended June 30, 2022 and increases to 1.1 to 1.0 for the periods thereafter; • a minimum adjusted EBITDA covenant of $4.7 million, excluding interest on accounts receivable from PREPA, for the five months ending May 31, 2022 was added; and • the minimum excess availability covenant was reduced to $7.5 million through the earlier of (i) March 31, 2022 or (ii) the date on which proceeds of permitted sale-leaseback transactions are received, after which the minimum excess availability covenant will increase to $10.0 million. The Fourth Amendment also permanently waived compliance by the borrowers with the leverage ratio and fixed charge coverage ratio covenants in the revolving credit facility for the fiscal quarters ended September 30, 2021 and December 31, 2021, respectively, ending the limited covenant waiver period under the Third Amendment. As of March 2, 2022, the Company had $83.7 million in borrowings outstanding under its revolving credit facility, leaving an aggregate of $10.6 million of available borrowing capacity under this facility, after giving effect to $8.5 million of outstanding letters of credit and the requirement to maintain a $7.5 million reserve out of the available borrowing capacity. If an event of default occurs under the revolving credit facility and remains uncured, it could have a material adverse effect on the Company ’ s business, financial condition, results of operations and cash flows. The lenders (i) would not be required to lend any additional amounts to the Company, (ii) could elect to increase the interest rate by 200 basis points, (iii) could elect to declare all outstanding borrowings, together with accrued and unpaid interest and fees, to be due and payable, (iv) may have the ability to require the Company to apply all of its available cash to repay outstanding borrowings, and (v) may foreclose on substantially all of the Company’s assets. As of March 2, 2022, the Company was in compliance with the covenants under its revolving credit facility, as amended and waived by the Third Amendment and Fourth Amendment. Aviation Note On November 6, 2020, Leopard and Cobra Aviation entered into a 39 month promissory note agreement with Bank7 (the “Aviation Note”) in an aggregate principal amount of $4.6 million and received net proceeds of $4.5 million. The Aviation Note bears interest at a rate based on the Wall Street Journal Prime Rate plus a margin of 1%. Principal and interest payments of $0.1 million are due monthly, with a final payment of $0.2 million due on February 1, 2024. The Aviation Note is collateralized by Leopard and Cobra Aviation’s assets, including a $1.8 million certificate of deposit. The Aviation Note contains various customary affirmative and restrictive covenants, all of which the Company was in compliance with as of December 31, 2021. As of December 31, 2021, the Company did not meet the minimum debt coverage ratio of 1.25 to 1.0 set forth in the Aviation Note. On March 2, 2022, Bank7 granted the Company a waiver of this event of default. The waiver extended the minimum cash requirement until June 30, 2022. |
Variable Interest Entities
Variable Interest Entities | 12 Months Ended |
Dec. 31, 2021 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Variable Interest Entities | Variable Interest Entities Dire Wolf and Predator Aviation, wholly owned subsidiaries of the Company, are party to Voting Trust Agreements with TVPX Aircraft Solutions Inc. (the “Voting Trustee”). Under the Voting Trust Agreements, Dire Wolf transferred 100% of its membership interest in Cobra Aviation and Predator Aviation transferred 100% of its membership interest in Leopard to the respective Voting Trustees in exchange for Voting Trust Certificates. Dire Wolf and Predator Aviation retained the obligation to absorb all expected returns or losses of Cobra Aviation and Leopard. Prior to the transfer of the membership interest to the Voting Trustee, Cobra Aviation was a wholly owned subsidiary of Dire Wolf and Leopard was a wholly owned subsidiary of Predator Aviation. Cobra Aviation owns two helicopters and support equipment, 100% of the equity interest in ARS and 49% of the equity interest in Brim Acquisitions. Leopard owns one helicopter. Dire Wolf and Predator Aviation entered into the Voting Trust Agreements in order to meet certain registration requirements. |
Selling, General and Administra
Selling, General and Administrative Expense | 12 Months Ended |
Dec. 31, 2021 | |
Other Income and Expenses [Abstract] | |
Selling, General And Administrative Expense | Selling, General and Administrative Expense Selling, general and administrative (“SG&A”) expense includes of the following (in thousands): Years Ended December 31, 2021 2020 2019 Cash expenses: Compensation and benefits $ 15,064 $ 14,876 $ 19,364 Professional services 11,400 19,905 17,128 Other (a) 9,052 8,828 10,300 Total cash SG&A expense 35,516 43,609 46,792 Non-cash expenses: Bad debt provision (b) 41,662 21,958 1,434 Stock based compensation 1,068 1,618 3,326 Total non-cash SG&A expense 42,730 23,576 4,760 Total SG&A expense $ 78,246 $ 67,185 $ 51,552 a. Includes travel-related costs, information technology expenses, rent, utilities and other general and administrative-related costs. b. The bad debt provision for the year ended December 31, 2021 includes $41.2 million related to the Stingray Pressure Pumping and Muskie contracts with Gulfport. The bad debt provision for the year ended December 31, 2020, included $19.4 million related to the voluntary petitions for relief filed on November 13, 2020, by Gulfport and certain of its subsidiaries. See Notes 2 and 19. |
Income Taxes
Income Taxes | 12 Months Ended |
Dec. 31, 2021 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | Income Taxes The components of income tax benefit attributable to the Company for the year ended December 31, 2021, 2020 and 2019, respectively, are as follows (in thousands): Year Ended December 31, 2021 2020 2019 U.S. current income tax expense (benefit) $ 290 $ (6,931) $ 386 U.S. deferred income tax benefit (23,740) (12,330) (21,761) Foreign current income tax expense 8,852 6,948 30,172 Foreign deferred income tax (benefit) expense (8,265) 144 (20,878) Total $ (22,863) $ (12,169) $ (12,081) A reconciliation of the statutory federal income tax amount to the recorded expense is as follows (in thousands): Year Ended December 31, 2021 2020 2019 Loss before income taxes $ (124,293) $ (119,776) $ (91,125) Statutory income tax rate 21 % 21 % 21 % Expected income tax (benefit) expense (26,102) (25,153) (19,136) Change in tax rate — (161) — Change in uncertain tax positions 1,043 — — Foreign income tax rate differential (282) 2,556 9,387 Foreign (loss) earnings not in reported income (336) 3,252 12,581 Foreign tax credits (7,749) (7,133) (26,141) Withholding taxes (49) 1,019 3,635 Goodwill impairment 52 11,544 6,506 Other permanent differences 426 1,290 1,873 State tax expenses (2,449) (1,664) 2,364 CARES act — (2,378) — Return to provision 390 894 (15,156) Change in valuation allowance 12,193 3,765 12,006 Total $ (22,863) $ (12,169) $ (12,081) The Company’s effective tax rate was 18.4% for the year ended December 31, 2021 compared to 10.2% for the year ended December 31, 2020 and 13.3% for the year ended December 31, 2019. The effective tax rate for the year ended December 31, 2021 differed from the statutory rate of 21% primarily due to the mix of earnings between the United States and Puerto Rico as well as changes in the valuation allowance. Additionally, the Company recorded an unrecognized tax benefit of $1.0 million during the year ended December 31, 2021 related to the 2020 tax year returns in Puerto Rico. On March 27, 2020, the Coronavirus Aid, Relief, and Economic Security (CARES) Act was enacted and signed into U.S. law in response to the COVID-19 pandemic, and among other things, permits the carryback of certain net operating losses. As a result of the enacted legislation, the Company recognized a $2.4 million net tax benefit during the year ended December 31, 2020, which consisted of a $7.0 million current tax benefit and a $4.6 million deferred tax expense. This impact, along with the rate impact from non-deductible goodwill impairment and the change in valuation allowance, was the primary driver for the difference between the statutory rate of 21% and the effective tax rate for the years ended December 31, 2020. The effective tax rate for the year ended December 31, 2019 differed from the statutory rate of 21% primarily due to the mix of earnings between the United States and Puerto Rico. For the year ended December 31, 2019, the Company recognized a loss in the United States, which was partially offset by earnings from its operations in Puerto Rico, which has a higher statutory rate compared to the United States. Additionally, during the year ended December 31, 2019, the Company recorded a benefit related to return to provision adjustments, which was partially offset by changes in the valuation allowance. Deferred tax liabilities attributable to the Company consisted of the following (in thousands): Year Ended December 31, 2021 2020 Deferred tax assets: Allowance for doubtful accounts $ 1,241 $ 1,541 Lease asset 4,432 6,060 Intangible assets 1,070 — Accrued liabilities 12,833 740 Net operating loss carryover 13,447 613 Foreign tax credits 83,780 80,615 Other 1,652 1,919 Valuation allowance (71,612) (67,888) Deferred tax assets 46,843 23,600 Deferred tax liabilities: Property and equipment $ (28,126) $ (39,057) Intangible assets — (450) Lease liability (4,392) (6,030) Other (7,096) (2,804) Deferred tax liabilities (39,614) (48,341) Net deferred tax asset (liability) $ 7,229 $ (24,741) Reflected in accompanying balance sheet as: Deferred income tax asset $ 8,094 $ — Deferred income tax liability (865) (24,741) Total $ 7,229 $ (24,741) During the years ended December 31, 2021 and 2020, the Company recorded changes in its valuation allowance of $12.2 million and $3.8 million, respectively, related to excess foreign tax credits that are not expected to be utilized. The Company has foreign tax credits carryforwards of $83.8 million as of December 31, 2021. These credits have a 10 year carryforward period and begin to expire in 2028. The Company maintains a partial valuation allowance related to U.S. foreign tax credit carryforwards, as it cannot objectively assert that these deferred tax assets are more likely than not to be realized. All available positive and negative evidence was weighed to determine whether a valuation allowance was necessary. The more significant evidential matter is the higher foreign tax rate applied to foreign source income in comparison to the U.S. Federal tax rate of 21%. As a result, the Company’s has foreign tax credits in excess of the corresponding U.S. income tax liability for which the foreign tax credits are allowed as an offset and, therefore, are not likely to be realized. At December 31, 2021, the Company had undistributed earnings in its Puerto Rico foreign branch. The distribution of these undistributed earnings is subject to a withholding tax in Puerto Rico and since the Company intends to make these distributions in the future, the withholding tax has been accrued. A reconciliation of the beginning and ending amounts of liabilities associated with uncertain tax positions for the year ended December 31, 2021 is as follows ($ in thousands): Balance, January 1, 2021 $ — Additions for tax positions of prior years 1,043 Balance, December 31, 2021 $ 1,043 |
Leases
Leases | 12 Months Ended |
Dec. 31, 2021 | |
Leases [Abstract] | |
Leases | Leases Lessee Accounting The Company recognized a lease liability equal to the present value of the lease payments and a right-of-use asset representing its right to use the underlying asset for the lease term for all leases with a term in excess of 12 months. For operating leases, lease expense for lease payments is recognized on a straight-line basis over the lease term, while finance leases include both an operating expense and an interest expense component. For all leases with a term of 12 months or less, the Company has elected the practical expedient to not recognize lease assets and liabilities and recognizes lease expense for these short-term leases on a straight-line basis over the lease term. The Company’s operating leases are primarily for rail cars, real estate, and equipment and its finance leases are primarily for machinery and equipment. Generally, the Company does not include renewal or termination options in its assessment of the leases unless extension or termination for certain assets is deemed to be reasonably certain. The accounting for some of the Company’s leases may require significant judgment, which includes determining whether a contract contains a lease, determining the incremental borrowing rates to utilize in the net present value calculation of lease payments for lease agreements which do not provide an implicit rate and assessing the likelihood of renewal or termination options. Lease agreements that contain a lease and non-lease component are generally accounted for as a single lease component. The rate implicit in the Company’s leases is not readily determinable. Therefore, the Company uses its incremental borrowing rate based on information available at the commencement date of its leases in determining the present value of lease payments. The Company’s incremental borrowing rate reflects the estimated rate of interest that it would pay to borrow on a collateralized basis over a similar term an amount equal to the lease payments in a similar economic environment. Lease expense consisted of the following for the years ended December 31, 2021 and 2020 (in thousands): Year Ended December 31, 2021 2020 Operating lease expense $ 9,156 $ 13,735 Short-term lease expense 335 812 Finance lease expense: Amortization of right-of-use assets 1,582 1,311 Interest on lease liabilities 202 203 Total lease expense $ 11,275 $ 16,061 Supplemental balance sheet information related to leases as of December 31, 2021 and 2020 is as follows (in thousands): Year Ended December 31, 2021 2020 Operating leases: Operating lease right-of-use assets $ 12,168 $ 20,179 Current operating lease liability 5,942 8,618 Long-term operating lease liability 5,918 11,377 Finance leases: Property and equipment, net $ 6,065 $ 6,065 Accrued expenses and other current liabilities 1,834 1,499 Other liabilities 4,375 4,618 Other supplemental information related to leases for the years ended December 31, 2021 and 2020 is as follows (in thousands): Year Ended December 31, 2021 2020 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 9,284 $ 13,643 Operating cash flows from finance leases 202 203 Financing cash flows from finance leases 1,677 1,318 Right-of-use assets obtained in exchange for lease obligations: Operating leases $ 594 $ (10,260) Finance leases 1,750 2,431 ` Year Ended December 31, 2021 2020 Weighted-average remaining lease term: Operating leases 3.1 years 3.2 years Finance leases 3.3 years 4.2 years Weighted-average discount rate: Operating leases 3.3 % 3.5 % Finance leases 3.3 % 3.5 % Maturities of lease liabilities as of December 31, 2021 are as follows (in thousands): Operating Leases Finance Leases 2022 $ 6,214 $ 2,005 2023 3,600 2,261 2024 1,641 965 2025 517 524 2026 147 795 Thereafter 407 — Total lease payments 12,526 6,550 Less: Present value discount 666 341 Present value of lease payments $ 11,860 $ 6,209 Lessor Accounting Certain of the Company’s agreements with its customers for drilling services, aviation services and remote accommodation services contain an operating lease component under ASC 842 because (i) there are identified assets, (ii) the customer obtains substantially all of the economic benefits of the identified assets throughout the period of use and (iii) the customer directs the use of the identified assets throughout the period of use. The Company has elected to apply the practical expedient provided to lessors to combine the lease and non-lease components of a contract where the revenue recognition pattern is the same and where the lease component, when accounted for separately, would be considered an operating lease. The practical expedient also allows a lessor to account for the combined lease and non-lease components under ASC 606, Revenue from Contracts with Customers , when the non-lease component is the predominant element of the combined component. |
Leases | Leases Lessee Accounting The Company recognized a lease liability equal to the present value of the lease payments and a right-of-use asset representing its right to use the underlying asset for the lease term for all leases with a term in excess of 12 months. For operating leases, lease expense for lease payments is recognized on a straight-line basis over the lease term, while finance leases include both an operating expense and an interest expense component. For all leases with a term of 12 months or less, the Company has elected the practical expedient to not recognize lease assets and liabilities and recognizes lease expense for these short-term leases on a straight-line basis over the lease term. The Company’s operating leases are primarily for rail cars, real estate, and equipment and its finance leases are primarily for machinery and equipment. Generally, the Company does not include renewal or termination options in its assessment of the leases unless extension or termination for certain assets is deemed to be reasonably certain. The accounting for some of the Company’s leases may require significant judgment, which includes determining whether a contract contains a lease, determining the incremental borrowing rates to utilize in the net present value calculation of lease payments for lease agreements which do not provide an implicit rate and assessing the likelihood of renewal or termination options. Lease agreements that contain a lease and non-lease component are generally accounted for as a single lease component. The rate implicit in the Company’s leases is not readily determinable. Therefore, the Company uses its incremental borrowing rate based on information available at the commencement date of its leases in determining the present value of lease payments. The Company’s incremental borrowing rate reflects the estimated rate of interest that it would pay to borrow on a collateralized basis over a similar term an amount equal to the lease payments in a similar economic environment. Lease expense consisted of the following for the years ended December 31, 2021 and 2020 (in thousands): Year Ended December 31, 2021 2020 Operating lease expense $ 9,156 $ 13,735 Short-term lease expense 335 812 Finance lease expense: Amortization of right-of-use assets 1,582 1,311 Interest on lease liabilities 202 203 Total lease expense $ 11,275 $ 16,061 Supplemental balance sheet information related to leases as of December 31, 2021 and 2020 is as follows (in thousands): Year Ended December 31, 2021 2020 Operating leases: Operating lease right-of-use assets $ 12,168 $ 20,179 Current operating lease liability 5,942 8,618 Long-term operating lease liability 5,918 11,377 Finance leases: Property and equipment, net $ 6,065 $ 6,065 Accrued expenses and other current liabilities 1,834 1,499 Other liabilities 4,375 4,618 Other supplemental information related to leases for the years ended December 31, 2021 and 2020 is as follows (in thousands): Year Ended December 31, 2021 2020 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 9,284 $ 13,643 Operating cash flows from finance leases 202 203 Financing cash flows from finance leases 1,677 1,318 Right-of-use assets obtained in exchange for lease obligations: Operating leases $ 594 $ (10,260) Finance leases 1,750 2,431 ` Year Ended December 31, 2021 2020 Weighted-average remaining lease term: Operating leases 3.1 years 3.2 years Finance leases 3.3 years 4.2 years Weighted-average discount rate: Operating leases 3.3 % 3.5 % Finance leases 3.3 % 3.5 % Maturities of lease liabilities as of December 31, 2021 are as follows (in thousands): Operating Leases Finance Leases 2022 $ 6,214 $ 2,005 2023 3,600 2,261 2024 1,641 965 2025 517 524 2026 147 795 Thereafter 407 — Total lease payments 12,526 6,550 Less: Present value discount 666 341 Present value of lease payments $ 11,860 $ 6,209 Lessor Accounting Certain of the Company’s agreements with its customers for drilling services, aviation services and remote accommodation services contain an operating lease component under ASC 842 because (i) there are identified assets, (ii) the customer obtains substantially all of the economic benefits of the identified assets throughout the period of use and (iii) the customer directs the use of the identified assets throughout the period of use. The Company has elected to apply the practical expedient provided to lessors to combine the lease and non-lease components of a contract where the revenue recognition pattern is the same and where the lease component, when accounted for separately, would be considered an operating lease. The practical expedient also allows a lessor to account for the combined lease and non-lease components under ASC 606, Revenue from Contracts with Customers , when the non-lease component is the predominant element of the combined component. |
Dividends and Earnings (Loss) P
Dividends and Earnings (Loss) Per Share | 12 Months Ended |
Dec. 31, 2021 | |
Earnings Per Share [Abstract] | |
Dividends and Earnings (Loss) Per Share | Dividends and Earnings (Loss) Per Share Dividends On July 16, 2018, the Company initiated a quarterly dividend policy. As a result of oilfield market conditions and other factors, which include collections from PREPA, the Company’s Board of Directors suspended the quarterly cash dividend in the third quarter of 2019. The table below summarizes the dividends paid on the Company’s common stock. Per Share Total (in thousands) 2019 Paid on February 14, 2019 $ 0.125 $ 5,609 Paid on May 17, 2019 0.125 5,610 Total cash dividends $ 0.25 $ 11,219 Earnings (Loss) Per Share Year Ended December 31, 2021 2020 2019 (in thousands, except per share data) Basic loss per share: Allocation of earnings: Net loss $ (101,430) $ (107,607) $ (79,044) Weighted average common shares outstanding 46,428 45,644 45,011 Basic loss per share $ (2.18) $ (2.36) $ (1.76) Diluted loss per share: Allocation of earnings: Net loss $ (101,430) $ (107,607) $ (79,044) Weighted average common shares, including dilutive effect (a) 46,428 45,644 45,011 Diluted loss per share $ (2.18) $ (2.36) $ (1.76) |
Equity Based Compensation
Equity Based Compensation | 12 Months Ended |
Dec. 31, 2021 | |
Share-based Payment Arrangement [Abstract] | |
Equity Based Compensation | Equity Based Compensation Upon formation of certain operating entities by Wexford, Gulfport and Rhino, specified members of management (the “Specified Members”) and certain non-employee members (the “Non-Employee Members”) were granted the right to receive distributions from the operating entities after the contribution member’s unreturned capital balance was recovered (referred to as “Payout” provision). On November 24, 2014, the awards were modified in conjunction with the contribution of the operating entities to Mammoth Inc. These awards were not granted in limited or general partner units. The awards are for interests in the distributable earnings of the members of MEH Sub, Mammoth Inc.’s majority equity holder. On the closing date of Mammoth Inc.’s initial public offering (“IPO”), the unreturned capital balance of Mammoth’s majority equity holder was not fully recovered from its sale of common stock in the IPO. As a result, Payout did not occur and no compensation cost was recorded. Payout for the remaining awards is expected to occur as the contribution member’s unreturned capital balance is recovered from additional sales by MEH Sub of its shares of the Company’s common stock or from dividend distributions, which is not considered probable until the event occurs. For the Specified Member awards, the unrecognized amount, which represents the fair value of the award as of the modification dates or grant date, was $5.6 million. The 2016 Plan authorizes the Company’s Board of Directors or the compensation committee of the Company’s Board of Directors to grant restricted stock, restricted stock units, stock appreciation rights, stock options and performance awards. There are 4.5 million shares of common stock reserved for issuance under the 2016 Plan. Restricted Stock Units The fair value of restricted stock unit awards was determined based on the fair market value of the Company’s common stock on the date of the grant. This value is amortized over the vesting period. Forfeitures are recognized as incurred. A summary of the status and changes of the unvested shares of restricted stock under the 2016 Plan is presented below. Number of Unvested Restricted Stock Units Weighted Average Grant-Date Fair Value Unvested restricted stock units as of January 1, 2019 434,119 $ 22.78 Granted 101,181 6.83 Vested (231,896) 22.45 Forfeited (82,163) 18.55 Unvested restricted stock units as of December 31, 2019 221,241 22.43 Granted 2,401,446 0.98 Vested (660,738) 5.32 Forfeited (47,167) 3.28 Unvested restricted stock units as of December 31, 2020 1,914,782 1.21 Granted 128,205 3.90 Vested (914,782) 1.52 Forfeited — — Unvested restricted stock units as of December 31, 2021 1,128,205 1.27 As of December 31, 2021, there was $0.8 million of total unrecognized compensation cost related to the unvested restricted stock. The cost is expected to be recognized over a weighted average period of approximately 1.0 year. |
Stock-Based Compensation
Stock-Based Compensation | 12 Months Ended |
Dec. 31, 2021 | |
Share-based Payment Arrangement [Abstract] | |
Stock-Based Compensation | Equity Based Compensation Upon formation of certain operating entities by Wexford, Gulfport and Rhino, specified members of management (the “Specified Members”) and certain non-employee members (the “Non-Employee Members”) were granted the right to receive distributions from the operating entities after the contribution member’s unreturned capital balance was recovered (referred to as “Payout” provision). On November 24, 2014, the awards were modified in conjunction with the contribution of the operating entities to Mammoth Inc. These awards were not granted in limited or general partner units. The awards are for interests in the distributable earnings of the members of MEH Sub, Mammoth Inc.’s majority equity holder. On the closing date of Mammoth Inc.’s initial public offering (“IPO”), the unreturned capital balance of Mammoth’s majority equity holder was not fully recovered from its sale of common stock in the IPO. As a result, Payout did not occur and no compensation cost was recorded. Payout for the remaining awards is expected to occur as the contribution member’s unreturned capital balance is recovered from additional sales by MEH Sub of its shares of the Company’s common stock or from dividend distributions, which is not considered probable until the event occurs. For the Specified Member awards, the unrecognized amount, which represents the fair value of the award as of the modification dates or grant date, was $5.6 million. The 2016 Plan authorizes the Company’s Board of Directors or the compensation committee of the Company’s Board of Directors to grant restricted stock, restricted stock units, stock appreciation rights, stock options and performance awards. There are 4.5 million shares of common stock reserved for issuance under the 2016 Plan. Restricted Stock Units The fair value of restricted stock unit awards was determined based on the fair market value of the Company’s common stock on the date of the grant. This value is amortized over the vesting period. Forfeitures are recognized as incurred. A summary of the status and changes of the unvested shares of restricted stock under the 2016 Plan is presented below. Number of Unvested Restricted Stock Units Weighted Average Grant-Date Fair Value Unvested restricted stock units as of January 1, 2019 434,119 $ 22.78 Granted 101,181 6.83 Vested (231,896) 22.45 Forfeited (82,163) 18.55 Unvested restricted stock units as of December 31, 2019 221,241 22.43 Granted 2,401,446 0.98 Vested (660,738) 5.32 Forfeited (47,167) 3.28 Unvested restricted stock units as of December 31, 2020 1,914,782 1.21 Granted 128,205 3.90 Vested (914,782) 1.52 Forfeited — — Unvested restricted stock units as of December 31, 2021 1,128,205 1.27 As of December 31, 2021, there was $0.8 million of total unrecognized compensation cost related to the unvested restricted stock. The cost is expected to be recognized over a weighted average period of approximately 1.0 year. |
Related Party Transactions
Related Party Transactions | 12 Months Ended |
Dec. 31, 2021 | |
Related Party Transactions [Abstract] | |
Related Party Transactions | Related Party Transactions Transactions between the subsidiaries of the Company and the following companies are included in Related Party Transactions: Wexford, Gulfport; Grizzly Oil Sands ULC (“Grizzly”); El Toro Resources LLC (“El Toro”); Everest Operations Management LLC (“Everest”); Elk City Yard LLC (“Elk City Yard”); Double Barrel Downhole Technologies LLC (“DBDHT”); Caliber Investment Group LLC (“Caliber”); Predator Drilling LLC (“Predator”); and Brim Equipment. Following is a summary of related party transactions (in thousands): Years Ended December 31, At December 31, 2021 2020 2019 2021 2020 REVENUES ACCOUNTS RECEIVABLE Stingray Pressure Pumping and Gulfport (a) $ 14,812 $ 42,460 $ 90,357 $ — $ 25,429 Muskie and Gulfport (b) 2,145 7,500 27,689 — 1,127 SR Energy and Gulfport (c) — 113 8,772 — 8 Aquahawk and Gulfport (d) — — 828 — — Cobra Aviation/ARS/Leopard and Brim Equipment (e) 371 446 2,093 85 44 Panther and El Toro (f) 599 38 573 — — Other Relationships 12 34 1 3 9 $ 17,939 $ 50,591 $ 130,313 $ 88 $ 26,617 OTHER ACCOUNTS RECEIVABLE Stingray Pressure Pumping and Gulfport (a) $ 514 $ 1,887 $ — $ — $ 1,841 Muskie and Gulfport (b) 1 3 — — 3 $ 515 $ 1,890 $ — $ — $ 1,844 $ 88 $ 28,461 a. Stingray Pressure Pumping provided pressure pumping, stimulation and related completion services to Gulfport. Other amount represents interest charged on delinquent accounts receivable related to these services. On June 29, 2021, Gulfport ceased to be a related party. See Note 3. b. Muskie agreed to sell and deliver, and Gulfport has agreed to purchase, specified annual and monthly amounts of natural sand proppant, subject to certain exceptions specified in the agreement, and pay certain costs and expenses. Other amount represents interest charged on delinquent accounts receivable related to this agreement. On June 29, 2021, Gulfport ceased to be a related party. See Note 3. c. SR Energy provided rental services for Gulfport. On June 29, 2021, Gulfport ceased to be a related party. d. Aquahawk provided water transfer services for Gulfport pursuant to a master services agreement. e. Cobra Aviation, ARS and Leopard lease helicopters to Brim Equipment pursuant to aircraft lease and management agreements. f. Panther provides directional drilling services for El Toro, an affiliate of Wexford, pursuant to a master service agreement. COST OF REVENUE ACCOUNTS PAYABLE Years Ended December 31, At December 31, 2021 2020 2019 2021 2020 Cobra Aviation/ARS/Leopard and Brim Equipment (a) 73 72 4,720 5 1 The Company and Caliber (b) 351 248 — — — Other Relationships 107 98 50 — — $ 531 $ 418 $ 4,770 $ 5 $ 1 SELLING, GENERAL AND ADMINISTRATIVE COSTS The Company and Wexford (c) 5 3 650 — 2 The Company and Caliber (b) 374 774 785 — — Cobra Aviation/ARS/Leopard and Brim Equipment (a) — — 233 — Other Relationships 8 (19) 179 — — $ 387 $ 758 $ 1,847 $ — $ 2 CAPITAL EXPENDITURES Leopard and Brim Equipment (a) — — 420 — — $ — $ — $ 420 $ — $ — $ 5 $ 3 a. Cobra Aviation, ARS and Leopard lease helicopters to Brim Equipment pursuant to aircraft lease and management agreements. b. Caliber, an entity controlled by Wexford, leases office space to the Company. c. Wexford provides certain administrative and analytical services to the Company and, from time to time, the Company pays for goods and services on behalf of Wexford. On December 21, 2018, Cobra Aviation acquired all outstanding equity interest in ARS and purchased two commercial helicopters, spare parts, support equipment and aircraft documents from Brim Equipment. Following these transactions, and also on December 21, 2018, Cobra Aviation formed a joint venture with Wexford Investments named Brim Acquisitions to acquire all outstanding equity interests in Brim Equipment. Cobra Aviation owns a 49% economic interest and Wexford Investment owns a 51% economic interest in Brim Acquisitions, and each member contributed its pro rata portion of Brim Acquisitions’ initial capital of $2.0 million. Cobra Aviation made additional investments in Brim Acquisitions totaling $0.5 million and $0.7 million during the years ended December 31, 2020 and 2019, respectively. Wexford Investments is an entity controlled by Wexford, which owns approximately 48% of the Company’s outstanding common stock. ARS leases a helicopter to Brim Equipment and Cobra Aviation leases the two helicopters purchased as part of these transactions to Brim Equipment under the terms of aircraft lease and management agreements. See Note 8 for further discussion. |
Commitments and Contingencies
Commitments and Contingencies | 12 Months Ended |
Dec. 31, 2021 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | Commitments and Contingencies Commitments The Company has entered into agreements with suppliers that contain minimum purchase obligations and agreements to purchase capital equipment. Aggregate future minimum payments under these obligations in effect at December 31, 2021 were approximately $1.4 million. Letters of Credit The Company has various letters of credit that were issued under the Company’s revolving credit facility which is collateralized by substantially all of the assets of the Company. The letters of credit are categorized below (in thousands): December 31, 2021 2020 Bonding program $ 1,000 $ 5,000 Environmental remediation 3,694 3,694 Insurance programs 3,890 3,890 Rail car commitments 455 455 Total letters of credit $ 9,039 $ 13,039 Insurance The Company has insurance coverage for physical partial loss to its assets, employer’s liability, automobile liability, commercial general liability, workers’ compensation and insurance for other specific risks. The Company has also elected in some cases to accept a greater amount of risk through increased deductibles on certain insurance policies. As of December 31, 2021 and 2020, the workers’ compensation and automobile liability policies required a deductible per occurrence of up to $0.3 million and $0.1 million, respectively. The Company establishes liabilities for the unpaid deductible portion of claims incurred based on estimates. As of December 31, 2021 and 2020, the workers’ compensation and auto liability policies contained an aggregate stop loss of $5.4 million. The Company establishes liabilities for the unpaid deductible portion of claims incurred relating to workers’ compensation and auto liability based on estimates. As of December 31, 2021 and 2020, accrued claims were $1.4 million and $1.9 million, respectively. The Company also has insurance coverage for directors and officers liability. As of December 31, 2021 and 2020, the directors and officers liability policy had a deductible per occurrence of $1.0 million and an aggregate deductible of $10.0 million. As of December 31, 2021 and 2020, the Company did not have any accrued claims for directors and officers liability. The Company also self-insures its employee health insurance. The Company has coverage on its self-insurance program in the form of a stop loss of $0.2 million per participant and an aggregate stop-loss of $5.8 million for the calendar year ending December 31, 2021. As of December 31, 2021 and 2020, accrued claims were $1.6 million and $1.3 million, respectively. These estimates may change in the near term as actual claims continue to develop. Warranty Guarantees Pursuant to certain customer contracts in our infrastructure services segment, the Company warrants equipment and labor performed under the contracts for a specified period following substantial completion of the work. Generally, the warranty is for one year or less. No liabilities were accrued as of December 31, 2021 or 2020 and no expense was recognized during the years ended December 31, 2021, 2020 or 2019 related to warranty claims. However, if warranty claims occur, the Company could be required to repair or replace warrantied items, which in most cases are covered by warranties extended from the manufacturer of the equipment. In the event the manufacturer of equipment failed to perform on a warranty obligation or denied a warranty claim made by the Company, the Company could be required to pay for the cost of the repair or replacement. Bonds In the ordinary course of business, the Company is required to provide bid bonds to certain customers in the infrastructure services segment as part of the bidding process. These bonds provide a guarantee to the customer that the Company, if awarded the project, will perform under the terms of the contract. Bid bonds are typically provided for a percentage of the total contract value. Additionally, the Company may be required to provide performance and payment bonds for contractual commitments related to projects in process. These bonds provide a guarantee to the customer that the Company will perform under the terms of a contract and that the Company will pay subcontractors and vendors. If the Company fails to perform under a contract or to pay subcontractors and vendors, the customer may demand that the surety make payments or provide services under the bond. The Company must reimburse the surety for expenses or outlays it incurs. As of December 31, 2021 and 2020, outstanding performance and payment bonds totaled $20.3 million and $18.1 million, respectively. The estimated cost to complete projects secured by the performance and payment bonds totaled $4.7 million as of December 31, 2021. As of December 31, 2021 and 2020, outstanding bid bonds totaled $0.6 million and $1.0 million, respectively. Litigation As of December 31, 2021, PREPA owed the Company approximately $227.0 million for services performed, excluding $110.8 million of interest charged on these delinquent balances as of December 31, 2021. The Company believes these receivables are collectible. PREPA, however, is currently subject to bankruptcy proceedings, which were filed in July 2017 and are currently pending in the U.S. District Court for the District of Puerto Rico. As a result, PREPA’s ability to meet its payment obligations is largely dependent upon funding from FEMA or other sources. On September 30, 2019, Cobra filed a motion with the U.S. District Court for the District of Puerto Rico seeking recovery of the amounts owed to Cobra by PREPA, which motion was stayed by the Court. On March 25, 2020, Cobra filed an urgent motion to modify the stay order and allow the recovery of approximately $61.7 million in claims related to a tax gross-up provision contained in the emergency master service agreement, as amended, that was entered into with PREPA on October 19, 2017. This emergency motion was denied on June 3, 2020 and the Court extended the stay of our motion. On December 9, 2020, the Court again extended the stay of our motion and directed PREPA to file a status motion by June 7, 2021. On April 6, 2021, Cobra filed a motion to lift the stay order. Following this filing, PREPA initiated discussion, which resulted in PREPA and Cobra filing a joint motion to adjourn all deadlines relative to the April 6, 2021 motion until the June 16, 2021 omnibus hearing as a result of PREPA’s understanding that FEMA would release a report in the near future relating to the emergency master service agreement between PREPA and Cobra that was executed on October 19, 2017. The joint motion was granted by the Court on April 14, 2021. On May 26, 2021, FEMA issued a Determination Memorandum related to the first contract between Cobra and PREPA in which, among other things, FEMA raised two contract compliance issues and, as a result, concluded that approximately $47 million in costs were not authorized costs under the contract. On June 14, 2021, the Court issued an order adjourning Cobra’s motion to lift the stay order to a hearing on August 4, 2021 and directing Cobra and PREPA to meet and confer in good faith concerning, among other things, (i) the May 26, 2021 Determination Memorandum issued by FEMA and (ii) whether and when a second determination memorandum is expected. The parties were further directed to file an additional status report, which was filed on July 20, 2021. On July 23, 2021, with the aid of Mammoth, PREPA filed an appeal of the entire $47 million that FEMA de-obligated in the May 26, 2021 Determination Memorandum. On August 4, 2021, the Court extended the stay and directed that an additional status report be filed, which was done on January 22, 2022. On January 26, 2022, the Court extended the stay and directed the parties to file a further status report by July 25, 2022. In the event PREPA (i) does not have or does not obtain the funds necessary to satisfy its obligations to Cobra under the contracts, (ii) obtains the necessary funds but refuses to pay the amounts owed to the Company or (iii) otherwise does not pay amounts owed to the Company for services performed, the receivable may not be collectible. On December 28, 2019, Gulfport filed a lawsuit against Stingray Pressure Pumping in the Superior Court of the State of Delaware. Pursuant to the complaint, Gulfport sought to terminate the October 1, 2014, Amended and Restated Master Services Agreement for Pressure Pumping Services between Gulfport and Stingray Pressure Pumping (“MSA”). In addition, Gulfport alleged breach of contract and sought damages for alleged overpayments and audit costs under the MSA and other fees and expenses associated with this lawsuit. On March 26, 2020, Stingray Pressure Pumping filed a counterclaim against Gulfport seeking to recover unpaid fees and expenses due to Stingray Pressure Pumping under the MSA. In September 2020, Muskie filed a lawsuit against Gulfport to recover delinquent payments due under a natural sand proppant supply contract. These matters were automatically stayed as a result of Gulfport’s bankruptcy filing on November 13, 2020, seeking voluntary relief under chapter 11 of the Bankruptcy Code. Gulfport emerged from bankruptcy on May 17, 2021. As of November 13, 2020, Gulfport owed the Company approximately $46.9 million, which included interest charges of $3.3 million and $1.8 million in attorneys’ fees. FASB ASC 326 , Financial Instruments-Credit Losses, requires companies to reflect its current estimate of all expected credit losses. As a result, the Company recorded reserves on its pre-petition receivables due from Gulfport for products and services, interest and attorneys’ fees of $19.4 million, $1.4 million and $1.8 million, respectively, during the year ended December 31, 2020. On March 22, 2021, Gulfport listed the Stingray Pressure Pumping and Muskie contracts on its master rejection schedule filed with the bankruptcy court. During the first quarter of 2021, the Company recognized unliquidated damages of approximately $46.4 million and recorded reserves on these unliquidated damages as a reduction to revenue of $27.1 million and to bad debt expense of $3.8 million. Also during the first quarter of 2021, the Company recorded additional reserves on its pre-petition products and services and interest receivables of $6.1 million and $0.5 million, respectively. On September 21, 2021, the Company and Gulfport reached a settlement under which all litigation relating to the Stingray Pressure Pumping contract and the Muskie contract was terminated, Stingray Pressure Pumping released all claims against Gulfport and its subsidiaries with respect to Gulfport’s bankruptcy proceedings, each of the parties released all claims they had against the others with respect to the litigation matters discussed above and Muskie retained an allowed general unsecured claim against Gulfport of $3.1 million. As a result, during the three months ended September 30, 2021, the Company wrote off its remaining receivable related to the Stingray Pressure Pumping claim resulting in bad debt expense and other expense of $31.0 million and $1.3 million, respectively, and recorded additional bad debt expense related to the Muskie claim totaling $0.2 million. The Company had net accounts receivable due from Gulfport totaling $0.1 million as of December 31, 2021, which is included in “accounts receivable, net” on the balance sheets. On January 21, 2020, MasTec Renewables Puerto Rico, LLC (“MasTec”) filed a lawsuit against Mammoth Inc. and Cobra in the U.S. District Court for the Southern District of Florida. MasTec’s complaint asserted claims against the Company and Cobra Acquisitions for violations of the federal Racketeer Influenced and Corrupt Organizations Act (“RICO”), tortious interference and violations of Puerto Rico law. MasTec alleged that it sustained injuries to its business and property in an unspecified amount because it lost the opportunity to perform work in connection with rebuilding the energy infrastructure in Puerto Rico after Hurricane Maria under a services contract with a maximum value of $500 million due to the Company’s and Cobra’s wrongful interference, payment of bribes, and other inducement to a FEMA official. On April 1, 2020, the defendants filed a motion to dismiss the complaint. On October 14, 2020, the Court dismissed the RICO claims, and on November 18, 2020, dismissed the claims arising under the Puerto Rico statute and the cause of action for tortious interference with MasTec’s contract (but not its business relations), and dismissed Mammoth Inc. from the litigation. On August 2, 2021, in order to avoid the risks of further litigation, and with no admission of wrongdoing whatsoever, the Company reached an agreement to settle this matter. Under the terms of the agreement, Cobra paid $6.5 million to MasTec on August 2, 2021 and the Company guaranteed payment, by Cobra, of $9.25 million on both August 1, 2022 and December 1, 2022. The agreement bears interest at rates between 6% and 12% and includes an acceleration clause that requires Cobra to pay within ten days all unpaid amounts if Cobra collects $100 million or more of specified receivables. The settlement amount and legal expenses related to the matter of $25.0 million and $5.4 million, respectively, are reflected in “other, net” on the accompanying consolidated statement of comprehensive loss for the year ended December 31, 2021. As of December 31, 2021, $19.0 million was included in “accrued expenses and other current liabilities” in the accompanying consolidated balance sheets, which includes accrued interest of $0.5 million. On May 13, 2021, Foreman Electric Services, Inc. (“Foreman”) filed a petition against Mammoth Inc. and Cobra in the Oklahoma County District Court (Oklahoma State Court). The petition asserted claims against the Company and Cobra under federal RICO statutes and certain state-law causes of action. Foreman alleged that it sustained injuries to its business and property in the amount of $250 million due to the Company’s and Cobra’s wrongful interference, payment of bribes and other inducements to a FEMA official. On May 18, 2021, the Company removed this action to the United States District Court for the Western District of Oklahoma and filed a motion to dismiss on July 8, 2021. On July 29, 2021, Foreman voluntarily dismissed the action without prejudice. On December 14, 2021, Foreman re-filed its petition against Mammoth Inc. and Cobra in the Oklahoma Count District Court (Oklahoma State Court). On December 16, 2021, the Company again removed this action to the United States District Court for the Western District of Oklahoma. Foreman filed a motion to remand this action back to Oklahoma County District Court, which motion is under consideration by the federal court. The Company and Cobra filed a motion to dismiss on January 31, 2022, which is expected to be fully briefed by March 7, 2022. In a related matter, on January 12, 2022, a Derivative Complaint on behalf of nominal defendant Machine Learning Integration, LLC (“MLI”), which alleges it would have served as a sub-contractor to Foreman in Puerto Rico, was filed against the Company and Cobra in the U.S. District Court for the District of Puerto Rico arising from essentially the same facts as Foreman's action and asserting violations of federal RICO statutes and certain state law claims. MLI alleges it sustained injuries to its business and property in an unspecified amount because the Company’s and Cobra’s wrongful interference, payment of bribes and other inducements to a FEMA official prevented Foreman from obtaining work, and thereby prevented MLI, as Foreman's subcontractor, from obtaining work. These matters are still in the early stages and at this time, the Company is not able to predict the outcome of these claims or whether they will have a material impact on the Company’s business, financial condition, results of operations or cash flows. The Company is routinely involved in state and local tax audits. During 2015, the State of Ohio assessed taxes on the purchase of equipment the Company believes is exempt under state law. The Company appealed the assessment and a hearing was held in 2017. As a result of the hearing, the Company received a decision from the State of Ohio, which the Company appealed. On February 25, 2022, the Company received an unfavorable decision on the appeal. The Company intends to appeal the decision and while it is not able to predict the outcome of the appeal, this matter is not expected to have a material adverse effect on the Company’s business, financial condition, results of operations or cash flows. On June 19, 2018, Wendco of Puerto Rico Inc. filed a putative class action lawsuit in the Commonwealth of Puerto Rico styled Wendco of Puerto Rico Inc.; Multisystem Restaurant Inc.; Restaurant Operators Inc.; Apple Caribe, Inc.; on their own behalf and in representation of all businesses that conduct business in the Commonwealth of Puerto Rico vs. Mammoth Energy Services Inc.; Cobra Acquisitions LLC; D. Grimm Puerto Rico, LLC, et al. The plaintiffs allege that the defendants caused power outages in Puerto Rico while performing restoration work on Puerto Rico’s electrical network following Hurricanes Irma and Maria in 2017, thereby interrupting commercial activities and causing economic loss. The parties have agreed to a settlement in principle and are in the process of documenting the settlement. Until the settlement agreement is executed, however, the Company is not able to predict the outcome of this lawsuit or whether it will have a material impact on the Company’s business, financial condition, results of operations or cash flows. Cobra has been served with ten lawsuits from municipalities in Puerto Rico alleging failure to pay construction excise and volume of business taxes. These matters are in various stages in the Court. At this time, the Company is not able to predict the outcome of these matters or whether they will have a material impact on the Company’s business, financial condition, results of operations or cash flows. On March 20, 2019, EJ LeJeune, a former employee of ESPADA Logistics and Security Group, LLC and ESPADA Caribbean LLC (together, “ESPADA”) filed a putative collective and class action complaint in LeJeune v. Mammoth Energy Services, Inc. d/b/a Cobra Energy & ESPADA Logistics and Security Group, LLC, Case No. 5:19-cv-00286-JKP-ESC, in the U.S. District Court for the Western District of Texas. On August 5, 2019, the Court granted the plaintiff’s motion for leave to amend his complaint, dismissing Mammoth Energy Services, Inc. as a defendant, adding Cobra Acquisitions LLC (“Cobra”) as a defendant, and adding ESPADA Caribbean LLC and two officers of ESPADA—James Jorrie and Jennifer Gay Jorrie—as defendants. The amended complaint alleges that the defendants jointly employed the plaintiff and all similarly situated workers and failed to pay them overtime as required by the Fair Labor Standards Act and Puerto Rico law. The complaint also alleges the following violations of Puerto Rico law: illegal deductions from workers’ wages, failure to timely pay all wages owed, failure to pay a required severance when terminating workers without just cause, failure to pay for all hours worked, failure to provide required meal periods, and failure to pay a statutorily required bonus to eligible workers. Mr. LeJeune seeks to represent a class of workers allegedly employed by one or more defendants and paid a flat amount for each day worked regardless of how many hours were worked. The complaint seeks back wages, including overtime wages owed, liquidated damages equal to the overtime wages owed, attorneys’ fees, costs, and pre- and post-judgment interest. On June 16, 2020, Cobra answered Mr. LeJeune’s amended complaint, denying that it employed Mr. LeJeune and the putative class members and denying that they are entitled to relief from Cobra. All other defendants have also answered the amended complaint. The parties stipulated to conditional certification of a collective action, and on August 14, 2020, Court ordered that notice be sent to all individuals engaged by ESPADA to provide services to Cobra in Puerto Rico between January 21, 2017 and the present who were paid a day-rate. Notice was sent to putative class members on September 15, 2020, and the opt-in period closed on November 14, 2020. The parties informed the Court that that the plaintiff and the ESPADA defendants reached a settlement on November 5, 2021, and subsequently, that a settlement was reached between the plaintiffs and Cobra on December 6, 2021. The stipulation of dismissal as to all parties was filed with the Court and the case was dismissed on January 19, 2022. On April 16, 2019, Christopher Williams, a former employee of Higher Power Electrical, LLC, filed a putative class and collective action complaint titled Christopher Williams, individually and on behalf of all others similarly situated v. Higher Power Electrical, LLC, Cobra Acquisitions LLC, and Cobra Energy LLC in the U.S. District Court for the District of Puerto Rico. On June 24, 2019, the complaint was amended to replace Mr. Williams with Matthew Zeisset as the named plaintiff. The plaintiff alleges that the Company failed to pay overtime wages to a class of workers in compliance with the Fair Labor Standards Act and Puerto Rico law. On August 21, 2019, upon request of the parties, the Court stayed proceedings in the lawsuit pending completion of individual arbitration proceedings initiated by Mr. Zeisset and opt-in plaintiffs. The arbitrations remain pending. Other claimants have subsequently initiated additional individual arbitration proceedings asserting similar claims. All complainants and the respondents have paid the filing fees necessary to initiate the arbitrations. The parties are currently engaged in discovery. The Company believes these claims are without merit and will vigorously defend the arbitrations. However, at this time, the Company is not able to predict the outcomes of these proceedings or whether they will have a material impact on the Company’s business, financial condition, results of operations or cash flows. In June 2019 and August 2019, the Company was served with three class action lawsuits filed in the Western District of Oklahoma. On September 13, 2019, the Court consolidated the three lawsuits under the case caption In re Mammoth Energy Services, Inc. Securities Litigation . On November 12, 2019, the plaintiffs filed their first amended complaint against Mammoth Energy Services, Inc., Arty Straehla, and Mark Layton. Pursuant to their first amended complaint, the plaintiffs brought a consolidated putative federal securities class action on behalf of all investors who purchased or otherwise acquired Mammoth Energy Services, Inc. common stock between October 19, 2017, and June 5, 2019, inclusive. On January 10, 2020, the defendants filed their motion to dismiss the first amended complaint. On March 9, 2020, the plaintiffs filed a second amended complaint for violation of federal securities laws which contains allegations substantially similar to those contained in the plaintiff’s first amended complaint. On March 30, 2020, the defendants filed their motion to dismiss the second amended complaint. On January 26, 2021, the Court granted the motion to dismiss in part and denied the motion to dismiss in part. In April 2021 a settlement was reached and motion for preliminary approval was filed, which the Court granted on May 4, 2021. On September 21, 2021, the Court issued a final judgment approving the settlement, which released the defendants from all claims asserted in the litigation, or that could have been asserted arising from the subject matter of the litigation and the purchase or acquisition of Mammoth common stock during the class period in return for a cash payment in the amount of $11.0 million for the benefit of the settlement class. The settlement amount is covered in full under Mammoth’s directors’ and officers’ insurance policy. In September 2019, four derivative lawsuits were filed, two in the Western District of Oklahoma and two in the District of Delaware, purportedly on behalf of the Company and against its officers and directors. In October 2019, the plaintiffs in the two Oklahoma actions voluntarily dismissed their respective cases, with one plaintiff refiling his action in the District of Delaware. On September 13, 2019, the Court consolidated the three actions under the case caption In re Mammoth Energy Services, Inc. Consolidated Shareholder Litigation. On January 17, 2020, the plaintiffs filed their consolidated amended shareholder derivative complaint on behalf of Nominal Defendant, Mammoth Energy Services, Inc., and against Arty Straehla, Mark Layton, Arthur Amron, Paul V. Heerwagen IV, Marc McCarthy, Jim Palm, Matthew Ross, Arthur Smith, Gulfport Energy Corporation, and Wexford Capital LP. On October 5, 2021, the plaintiffs and Nominal Defendant Mammoth entered into the Stipulation and Agreement of Settlement (the “Stipulation”) in the derivative action, which was preliminarily approved by the Court on October 28, 2021. The terms of the Stipulation required that, in exchange for the full release, discharge and dismissal with prejudice of the claims asserted against the defendants in the derivative action, (1) the individual defendants will cause the insurers under Mammoth’s Directors’ and Officers’ (“D&O”) insurance policy (the “D&O insurers”) to pay $1.5 million to Mammoth, which Mammoth will use for general corporate purposes; and (2) Mammoth will adopt certain corporate governance reforms, which will further enhance Mammoth’s current corporate governance policies. Additionally, the Stipulation provides that the individual defendants will cause the D&O insurers to pay, subject to Court approval, a separate payment of $0.5 million to plaintiffs’ counsel for their attorneys’ fees and expenses. The approval hearing was held on January 25, 2022 and the final order was entered. The settlement was covered in full under Mammoth’s D&O insurance policy. On September 10, 2019, the U.S. District Court for the District of Puerto Rico unsealed an indictment that charged the former president of Cobra Acquisitions LLC with conspiracy, wire fraud, false statements and disaster fraud. Two other individuals were also charged in the indictment. The indictment is focused on the interactions between a former FEMA official and the former president of Cobra. Neither the Company nor any of its subsidiaries were charged in the indictment. The Company is continuing to cooperate with the related investigation. Given the uncertainty inherent in the criminal litigation, it is not possible at this time to determine the potential outcome or other potential impacts that the criminal litigation could have on the Company. PREPA has stated in Court filings that it may contend the alleged criminal activity affects Cobra’s entitlement to payment under its contracts with PREPA. Subsequent to the indictment, the Company received (i) a preservation request letter from the United States Securities and Exchange Commission (“SEC”) related to documents relevant to an ongoing investigation it is conducting and (ii) a civil investigative demand (“CID”) from the United States Department of Justice (“DOJ”), which requests certain documents and answers to specific interrogatories relevant to an ongoing investigation it is conducting. Both the aforementioned SEC and DOJ investigations are in connection with the issues raised in the criminal matter. Following the resignation of Jonathan Yellen from the Company’s board of directors and the matters raised in the Company’s Form 8-K filed on May 14, 2020, the Company received an expanded preservation request from the SEC. The Company is cooperating with both the SEC and DOJ and is not able to predict the outcome of these investigations or if either will have a material impact on the Company’s business, financial condition, results of operations or cash flows. On September 12, 2019, AL Global Services, LLC (“Alpha Lobo”) filed a second amended third-party petition against the Company in an action styled Jim Jorrie v. Craig Charles, Julian Calderas, Jr., and AL Global Services, LLC v. Jim Jorrie v. Cobra Acquisitions LLC v. ESPADA Logistics & Security Group, LLC, ESPADA Caribbean LLC, Arty Straehla, Ken Kinsey, Jennifer Jorrie, and Mammoth Energy Services, Inc., in the 57th Judicial District in Bexar County, Texas. The petition alleges that the Company should be held vicariously liable under alter ego, agency and respondeat superior theories for Alpha Lobo’s alleged claims against Cobra and Arty Straehla for aiding and abetting, knowing participation in and conspiracy to breach fiduciary duty in connection with Cobra’s execution of an agreement with ESPADA Caribbean, LLC for security services related to Cobra’s work in Puerto Rico. The case is currently subject to a statutory stay pending a ruling on the appeal of anti-SLAPP motions to dismiss filed by certain defendants. The Company believes these claims are without merit and will vigorously defend the action. However, at this time, the Company is not able to predict the outcome of this lawsuit or whether it will have a material impact on the Company’s business, financial condition, results of operations or cash flows. Additionally, there is a parallel arbitration proceeding that has been initiated in which certain Defendants are seeking a declaratory judgment regarding Cobra’s rights to terminate the Alpha Lobo contract and enter into a new contract with a third-party. On June 24, 2021, the arbitration panel ruled in favor of Cobra. Subsequently, the trial Court in this action granted Cobra, the Company and Straehla’s motion to compel arbitration. Alpha Lobo has not brought their claims in arbitration at this time. The Company is involved in various other legal proceedings in the ordinary course of business. Although the Company cannot predict the outcome of these proceedings, legal matters are subject to inherent uncertainties and there exists the possibility that the ultimate resolution of these matters could have a material impact on the Company’s business, financial condition, results of operations or cash flows. Defined contribution plan |
Reporting Segments and Geograph
Reporting Segments and Geographic Areas | 12 Months Ended |
Dec. 31, 2021 | |
Segment Reporting [Abstract] | |
Reporting Segments and Geographic Areas | Reporting Segments and Geographic Areas Reporting Segments As of December 31, 2021, the Company’s revenues, income before income taxes and identifiable assets are primarily attributable to four reportable segments. The Company principally provides electric infrastructure services to private utilities, public investor-owned utilities and co-operative utilities and services in connection with on-shore drilling of oil and natural gas wells for small to large domestic independent oil and natural gas producers. The Company’s Chief Executive Officer and Chief Financial Officer comprise the Company’s Chief Operating Decision Maker function (“CODM”). Segment information is prepared on the same basis that the CODM manages the segments, evaluates the segment financial statements and makes key operating and resource utilization decisions. Segment evaluation is determined on a quantitative basis based on a function of operating loss less impairment expense, as well as a qualitative basis, such as nature of the product and service offerings and types of customers. As of December 31, 2021, the Company’s four reportable segments include infrastructure services (“Infrastructure”), well completion services (“Well Completion”), natural sand proppant services (“Sand”) and drilling services (“Drilling”). Prior to the year ended December 31, 2021, the Company included Aquawolf in its “All Other” reconciling column. Based on its assessment of FASB ASC 280, Segment Reporting , guidance at December 31, 2021, the Company changed its presentation in 2021 to move Aquawolf to the Infrastructure segment. The results for the years ended December 31, 2020 and 2019 have been retroactively adjusted to reflect this change. The Infrastructure segment provides electric utility infrastructure services to government-funded utilities, private utilities, public investor-owned utilities and co-operative utilities in the northeastern, southwestern, midwestern and western portions of the United States. The Well Completion segment provides hydraulic fracturing and water transfer services primarily in the Utica Shale of Eastern Ohio, Marcellus Shale in Pennsylvania and the mid-continent region. The Sand segment mines, processes and sells sand for use in hydraulic fracturing. The Sand segment primarily services the Utica Shale, Permian Basin, SCOOP, STACK and Montney Shale in British Columbia and Alberta, Canada. During certain of the periods presented, the Drilling segment provided contract land and directional drilling services primarily in the Permian Basin and mid-continent region. During certain of the periods presented, the Company also provided aviation services, coil tubing services, equipment rental services, full service transportation, crude oil hauling services, remote accommodation and equipment manufacturing. The businesses that provide these services are distinct operating segments, which the CODM reviews independently when making key operating and resource utilization decisions. None of these operating segments meet the quantitative thresholds of a reporting segment and do not meet the aggregation criteria set forth in ASC 280 Segment Reporting. Therefore, results for these operating segments are included in the column titled “All Other” in the tables below. Additionally, assets for corporate activities, which primarily include cash and cash equivalents, inter-segment accounts receivable, prepaid insurance and certain property and equipment, are included in the All Other column. Although Mammoth Energy Partners LLC, which holds these corporate assets, meets one of the quantitative thresholds of a reporting segment, it does not engage in business activities from which it may earn revenues and its results are not regularly reviewed by the Company’s CODM when making key operating and resource utilization decisions. Therefore, the Company does not include it as a reportable segment. Sales from one segment to another are generally priced at estimated equivalent commercial selling prices. Total revenue and total cost of revenue amounts included in the Eliminations column in the following tables include inter-segment transactions conducted between segments. Receivables due for sales from one segment to another and for corporate allocations to each segment are included in the Eliminations column for total assets in the following tables. All transactions conducted between segments are eliminated in consolidation. Transactions conducted by companies within the same reporting segment are eliminated within each reporting segment. The following tables set forth certain financial information with respect to the Company’s reportable segments (in thousands): Year Ended December 31, 2021 Infrastructure Well Completion Sand Drilling All Other Eliminations Total Revenue from external customers $ 93,403 $ 84,190 $ 30,880 $ 4,197 $ 16,292 $ — $ 228,962 Intersegment revenues — 144 3,980 124 2,218 (6,466) — Total revenue 93,403 84,334 34,860 4,321 18,510 (6,466) 228,962 Cost of revenue, exclusive of depreciation, depletion, amortization and accretion 90,363 58,782 27,232 6,102 15,847 — 198,326 Intersegment cost of revenues 196 5,770 — — 500 (6,466) — Total cost of revenue 90,559 64,552 27,232 6,102 16,347 (6,466) 198,326 Selling, general and administrative 18,267 49,275 5,351 1,414 3,939 — 78,246 Depreciation, depletion, amortization and accretion 21,880 26,377 9,005 7,996 13,217 — 78,475 Impairment of goodwill 891 — — — — — 891 Impairment of other long-lived assets 665 — — — 547 — 1,212 Operating loss (38,859) (55,870) (6,728) (11,191) (15,540) — (128,188) Interest expense 3,925 1,107 474 293 607 — 6,406 Other (income) expense, net (6,785) 1,073 (874) (177) (3,538) — (10,301) Loss before income taxes $ (35,999) $ (58,050) $ (6,328) $ (11,307) $ (12,609) $ — $ (124,293) Total expenditures for property, plant and equipment $ 627 $ 4,327 $ 484 $ 44 $ 361 $ — $ 5,843 As of December 31, 2021: Intangible assets, net $ 165 $ 1,995 $ — $ — $ 401 $ — $ 2,561 Total assets $ 427,626 $ 56,036 $ 156,519 $ 27,457 $ 129,202 $ (75,948) $ 720,892 Year Ended December 31, 2020 Infrastructure Well Completion Sand Drilling All Other Eliminations Total Revenue from external customers $ 157,751 $ 87,201 $ 34,265 $ 7,746 $ 26,113 $ — $ 313,076 Intersegment revenue — 1,124 95 39 2,716 (3,974) — Total revenue 157,751 88,325 34,360 7,785 28,829 (3,974) 313,076 Cost of revenue, exclusive of depreciation, depletion, amortization and accretion 124,232 45,647 25,955 10,757 25,430 — 232,021 Intersegment cost of revenues 323 1,836 — 152 1,663 (3,974) — Total cost of revenue 124,555 47,483 25,955 10,909 27,093 (3,974) 232,021 Selling, general and administrative 27,261 23,039 7,807 3,149 5,929 — 67,185 Depreciation, depletion, amortization and accretion 29,373 30,411 9,771 10,039 15,723 — 95,317 Impairment of goodwill — 53,406 — — 1,567 — 54,973 Impairment of other long-lived assets — 4,203 — 326 8,368 — 12,897 Operating loss (23,438) (70,217) (9,173) (16,638) (29,851) — (149,317) Interest expense 2,794 1,130 312 454 707 — 5,397 Other (income) expense, net (32,437) (2,274) 1,839 (227) (1,839) — (34,938) Income (loss) before income taxes $ 6,205 $ (69,073) $ (11,324) $ (16,865) $ (28,719) $ — $ (119,776) Total expenditures for property, plant and equipment $ 258 $ 4,358 $ 1,073 $ 432 $ 716 $ — $ 6,837 As of December 31, 2020: Intangible assets, net $ 1,063 $ 2,683 $ — $ — $ 1,028 $ — $ 4,774 Total assets $ 437,296 $ 99,247 $ 172,927 $ 36,252 $ 136,422 $ (57,582) $ 824,562 Year Ended December 31, 2019 Infrastructure Well Completion Sand Drilling All Other Eliminations Total Revenue from external customers $ 210,712 $ 241,951 $ 67,267 $ 31,728 $ 73,354 $ — $ 625,012 Intersegment revenues 2,573 1,851 29,796 236 15,232 (49,688) — Total revenue 213,285 243,802 97,063 31,964 88,586 (49,688) 625,012 Cost of revenue, exclusive of depreciation, depletion, amortization and accretion 160,731 174,816 87,637 35,925 84,679 — 543,788 Intersegment cost of revenues 12,820 31,727 15 1,028 4,158 (49,748) — Total cost of revenue 173,551 206,543 87,652 36,953 88,837 (49,748) 543,788 Selling, general and administrative 23,616 10,889 5,006 4,177 7,864 — 51,552 Depreciation, depletion, amortization and accretion 30,349 40,159 14,050 13,143 19,332 — 117,033 Impairment of goodwill — 23,423 2,684 — 7,557 — 33,664 Impairment of other long-lived assets — — — 2,955 4,403 — 7,358 Operating loss (14,231) (37,212) (12,329) (25,264) (39,407) 60 (128,383) Interest expense 1,674 1,228 193 862 1,001 — 4,958 Other expense (41,949) 580 67 (9) (905) — (42,216) (Loss) income before income taxes $ 26,044 $ (39,020) $ (12,589) $ (26,117) $ (39,503) $ 60 $ (91,125) Total expenditures for property, plant and equipment $ 3,456 $ 14,703 $ 2,877 $ 3,156 $ 11,569 $ — 35,761 As of December 31, 2019: Intangible assets, net $ 1,296 $ 3,371 $ — $ — $ 1,121 $ — $ 5,788 Total assets $ 420,755 $ 172,608 $ 189,415 $ 55,273 $ 166,406 $ (52,072) $ 952,385 Geographic Areas The following table presents consolidated revenues by country based on sales destination of the products or services (in thousands): Year Ended December 31, 2021 2020 2019 United States $ 217,958 $ 302,205 $ 516,276 Puerto Rico — 53 96,630 Canada 10,685 10,723 11,946 Other 319 95 160 Total $ 228,962 $ 313,076 $ 625,012 The following table presents long-lived assets, excluding deferred income tax assets, by country (in thousands): Year Ended December 31, 2021 2020 2019 United States $ 258,666 $ 342,838 $ 526,584 Canada 13,349 16,976 18,821 Total $ 272,015 $ 359,814 $ 545,405 |
Subsequent Events
Subsequent Events | 12 Months Ended |
Dec. 31, 2021 | |
Subsequent Events [Abstract] | |
Subsequent Events | Subsequent Events As discussed above, on February 28, 2022, the Company entered into a fourth amendment to its revolving credit facility. See Note 10 above for details. Subsequent to December 31, 2021, the Company ordered additional capital equipment with aggregate commitments of $2.7 million. |
Summary of Significant Accoun_2
Summary of Significant Accounting Policies (Policies) | 12 Months Ended |
Dec. 31, 2021 | |
Accounting Policies [Abstract] | |
Basis of Presentation | The accompanying consolidated financial statements were prepared in accordance with the rules and regulations of the Securities and Exchange Commission, and reflect all adjustments, which in the opinion of management are necessary for the fair presentation of the results. |
Principles of Consolidation | Principles of Consolidation The accompanying consolidated financial statements are prepared in accordance with GAAP and include the accounts of the Company and its subsidiaries and the variable interest entities (“VIE”) for which the Company is the primary beneficiary. All material intercompany accounts and transactions between the entities within the Company have been eliminated. |
Variable Interest Entity | Variable Interest EntitiesThe Company consolidates a VIE when it is determined to be the primary beneficiary, which is the party that has both (i) the power to direct the activities that most significantly impact the VIE’s economic performance and (ii) through its interests in the VIE, the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. See Note 11 for more information on the Company’s VIEs. |
Use of Estimates | Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates include, but are not limited to, the Company's sand reserves and their impact on calculating depletion expense, allowance for doubtful accounts, asset retirement obligations, reserves for self-insurance, depreciation and amortization of property and equipment, amortization of intangible assets and future cash flows, fair values used to assess recoverability and impairment of long-lived assets, including goodwill, estimates of income taxes and the estimated effects of litigation and other contingencies. |
Reclassifications | Reclassifications Certain reclassifications have been made to prior period amounts to conform to the current period financial statement presentation. The Company adopted a new accounting policy related to the classification of certain legal expenses. For matters related to ongoing operations, the Company continues to present legal expense as selling, general and administrative. For matters determined to be unrelated to ongoing operations, the Company classifies the legal expenses according to the nature of the underlying matter. The Company believes that this new accounting policy will more accurately present legal expenses on its consolidated statement of comprehensive loss. The adoption of this policy resulted in the recognition of approximately $5.4 million of legal expenses related to a certain legal settlement, which is included in Other, net on the consolidated statement of comprehensive loss for the year ended December 31, 2021. See Note 19 for additional information. |
Cash and Cash Equivalents and Short-Term Investment | Cash and Cash Equivalents and Short-Term InvestmentAll highly liquid investments with an original maturity of three months or less are considered cash equivalents. The Company maintains its cash accounts in financial institutions that are insured by the Federal Deposit Insurance Corporation, with the exception of cash held by Sand Tiger in a Canadian financial institution. Cash balances from time to time may exceed the insured amounts; however, the Company has not experienced any losses in such accounts and does not believe it is exposed to any significant credit risks on such accounts. The Company’s short-term investment consists of a certificate of deposit with a maturity over 90 days. |
Accounts Receivable | Accounts Receivable Accounts receivable include amounts due from customers for services performed or goods sold. The Company grants credit to customers in the ordinary course of business and generally does not require collateral. Prior to granting credit to customers, the Company analyzes the potential customer’s risk profile by utilizing a credit report, analyzing macroeconomic factors and using its knowledge of the industry, among other factors. Most areas in the continental United States in which the Company operates provide for a mechanic’s lien against the property on which the service is performed if the lien is filed within the statutorily specified time frame. Customer balances are generally considered delinquent if unpaid by the 30th day following the invoice date and credit privileges may be revoked if balances remain unpaid. Interest on delinquent trade accounts receivable is recognized in other, net on the consolidated statement of comprehensive loss when chargeable and collectability is reasonably assured. |
Inventory | Inventory Inventory consists of raw sand and processed sand available for sale, raw materials, chemicals and other products sold as a bi-product of completion and production operations and supplies used in performing services. Inventory is stated at the lower of cost or market (net realizable value) on an average cost basis. The Company assesses the valuation of its inventories based upon specific usage, future utility, obsolescence and other factors. Inventory manufactured at the Company’s sand production facilities includes direct excavation costs, processing costs and overhead allocation. Stockpile tonnages are calculated by measuring the number of tons added and removed from the stockpile. Costs are calculated on a per ton basis and are applied to the stockpiles based on the number of tons in the stockpile. Inventory transported for sale at the Company’s terminal facility includes the cost of purchased or manufactured sand, plus transportation related charges. Coil tubing strings of various widths, diameters and lengths are included in inventory. The strings are used in providing specialized services to customers who are primarily operators of oil or gas wells and are used at various rates based on factors such as well conditions (i.e. pressure and friction), vertical and horizontal length of the well, running speed of the |
Prepaid Expenses | Prepaid Expenses Prepaid expenses primarily consist of insurance costs and rail car freight and lease expense. These costs are expensed over the periods that they benefit. |
Property and Equipment | Property and Equipment Property and equipment, including renewals and betterments, are capitalized and stated at cost, while maintenance and repairs that do not increase the capacity, improve the efficiency or safety, or improve or extend the useful life are charged to operations as incurred. Disposals are removed at cost, less accumulated depreciation, and any resulting gain or loss is recorded in operations. Depreciation is calculated using the straight-line method over the shorter of the estimated useful life, or the remaining lease term, as applicable. Depreciation does not begin until property and equipment is placed in service. Once placed in service, depreciation on property and equipment continues while being repaired, refurbished, or between periods of deployment. |
Sand Reserves | Sand Reserves Sand reserve costs include engineering, mineralogical studies and other related costs to develop the mine, the removal of overburden to initially expose the mineral and building access ways. Exploration costs are expensed as incurred and classified as product cost of revenue. Capitalization of mine development project costs begins once the deposit is classified as proven and probable reserves. Drilling and related costs are capitalized for deposits where proven and probable reserves exist and the activities are directed at obtaining additional information on the deposit or converting non-reserve minerals to proven and probable reserves and the benefit is to be realized over a period greater than one year. Mining property and development costs are amortized using the units-of-production method on estimated measured tons in in-place reserves. The impact of revisions to reserve estimates is recognized on a prospective basis. |
Long-Lived Assets | Long-Lived Assets The Company reviews long-lived assets for recoverability in accordance with the provisions of Financial Accounting Standards Board (“FASB”) Accounting Standard Codification (“ASC”) 360, Impairment or Disposal of Long-Lived Assets |
Goodwill | GoodwillGoodwill is tested for impairment annually, or more frequently if events or changes in circumstances indicate that goodwill might be impaired. If it is determined that an impairment exists, an impairment charge is recognized for the excess of carrying value over implied fair value. The fair value is determined using a combination of the income and market approaches. |
Other Non-Current Assets | Other Non-Current AssetsOther non-current assets primarily consist of deferred financing costs on our credit facility (see Note 10), sales tax receivables and our equity method investment (see Note 8). Investments are accounted for under the equity method in circumstances where the Company has the ability to exercise significant influence over the operating and investing policies of the investee, but does not have control. Under the equity method, the Company recognizes its share of the investee’s earnings in its consolidated statements of comprehensive loss. Investments are evaluated for impairment and a charge to earnings is recognized when any identified impairment is determined to be other than temporary. |
Asset Retirement Obligations | Asset Retirement ObligationsMine reclamation costs, future remediation costs for inactive mines and other contractual site remediation costs are accrued based on management’s best estimate at the end of each period of the costs expected to be incurred at a site. Such cost estimates include, where applicable, ongoing care, maintenance and monitoring costs. Changes in estimates are reflected in earnings in the period an estimate is revised. |
Amortizable Intangible Assets | Amortizable Intangible Assets Intangible assets subject to amortization include customer relationships and trade names. Customer relationships are amortized based on an estimated attrition factor and trade names are amortized over their estimated useful lives. |
Fair Value of Financial Instruments | Fair Value of Financial Instruments The Company’s financial instruments consist of cash and cash equivalents, short-term investments, trade receivables, trade payables, amounts receivable or payable to related parties and long-term debt. The carrying amount of cash and cash equivalents, trade receivables, trade payables and receivables and payables from related parties approximates fair value because of the short-term nature of the instruments. The fair value of long-term debt approximates it s carrying value because the cost of borrowing fluctuates based upon market conditions. |
Revenue Recognition | Revenue Recognition The timing of revenue recognition may differ from contract billing or payment schedules, resulting in revenues that have been earned but not billed (“unbilled revenue”) or amounts that have been billed, but not earned (“deferred revenue”).The Company’s primary revenue streams include infrastructure services, well completion services, natural sand proppant services, drilling services and other services, which includes coil tubing, pressure control, flowback, cementing, acidizing, equipment rentals, full service transportation, crude oil hauling, remote accommodations and equipment manufacturing. See Note 20 for the Company’s revenue disaggregated by type. Certain of the Company’s customer contracts include provisions entitling the Company to a termination penalty when the customer invokes its contractual right to terminate prior to the contract’s nominal end date. The termination penalties in the customer contracts vary, but are generally considered substantive for accounting purposes and create enforceable rights and obligations throughout the stated duration of the contract. The Company accounts for a contract cancellation as a contract modification in the period in which the customer invokes the termination provision. The determination of the contract termination penalty is based on the terms stated in the related customer agreement. As of the modification date, the Company updates its estimate of the transaction price using the expected value method, subject to constraints, and recognizes the amount over the remaining performance period. Infrastructure Services Infrastructure services are typically provided pursuant to master service agreements, repair and maintenance contracts or fixed price and non-fixed price installation contracts. Pricing under these contracts may be unit priced, cost-plus/hourly (or time and materials basis) or fixed price (or lump sum basis). Generally, the Company accounts for infrastructure services as a single performance obligation satisfied over time. In certain circumstances, the Company supplies materials that are utilized during the jobs as part of the agreement with the customer. The Company accounts for these infrastructure agreements as multiple performance obligations satisfied over time. Revenue is recognized over time as work progresses based on the days completed or as the contract is completed. Under certain customer contracts in our infrastructure services segment, the Company warranties equipment and labor performed for a specified period following substantial completion of the work. Well Completion Services Well completion services are typically provided based upon a purchase order, contract or on a spot market basis. Services are provided on a day rate, contracted or hourly basis. Generally, the Company accounts for well completion services as a single performance obligation satisfied over time. In certain circumstances, the Company supplies proppant that is utilized for pressure pumping as part of the agreement with the customer. The Company accounts for these pressure pumping agreements as multiple performance obligations satisfied over time. Jobs for these services are typically short-term in nature and range from a few hours to multiple days. Generally, revenue is recognized over time upon the completion of each segment of work based upon a completed field ticket, which includes the charges for the services performed, mobilization of the equipment to the location and personnel. Pursuant to a contract with Gulfport, Stingray Pressure Pumping agreed to provide Gulfport with use of up to two pressure pumping fleets for the period covered by the contract. Under this agreement, performance obligations were satisfied as services were rendered based on the passage of time rather than the completion of each segment of work. Stingray Pressure Pumping had the right to receive consideration from this customer even if circumstances prevent us from performing work. All consideration owed to Stingray Pressure Pumping for services performed during the contractual period is fixed and the right to receive it is unconditional. On December 28, 2019, Gulfport filed a legal action in Delaware state court seeking the termination of this contract and monetary damages. Further, on November 13, 2020, Gulfport filed petitions for voluntary relief under chapter 11 of the Bankruptcy Code. On March 22, 2021, Gulfport listed the Stingray Pressure Pumping contract on its master rejection schedule filed with the bankruptcy court. The Company determined that these factors changed the scope of the contract, accelerated the duration of, and otherwise changed the rights and obligations of each party to the contract. As a result, the Company accounted for this as a contract modification during the three months ended March 31, 2021. Stingray Pressure Pumping used the expected value method to estimate unliquidated damages totaling $37.9 million, which resulted in the recognition of net revenue totaling $14.8 million and bad debt expense of $2.9 million on previously recognized revenue during the three months ended March 31, 2021. On September 21, 2021, the Company and Gulfport reached a settlement under which all litigation relating to the Stingray Pressure Pumping contract will be terminated. Stingray Pressure Pumping released all claims against Gulfport and its subsidiaries with respect to Gulfport’s bankruptcy proceedings and each of the parties released all claims they had against the others with respect to the litigation matters discussed in Note 19. As a result of this settlement agreement, during the three months ended September 30, 2021, the Company wrote off its remaining receivable related to the Stingray Pressure Pumping claim resulting in bad debt expense and other expense of $31.0 million and $1.3 million, respectively. Gulfport was a related party until June 29, 2021. On June 29, 2021, pursuant to the terms of its plan of reorganization, all of the Company’s shares that Gulfport owned were transferred to a trust for the benefit of certain of Gulfport’s creditors. The revenue recognized related to this agreement is included in “services revenue - related parties” in the accompanying consolidated statement of comprehensive loss and the related accounts receivable is included in “receivables due from related parties” as of December 31, 2020. See Notes 12 and 19 below. Additional revenue is generated through labor charges and the sale of consumable supplies that are incidental to the service being performed. Such amounts are recognized ratably over the period during which the corresponding goods and services are consumed. Natural Sand Proppant Services The Company sells natural sand proppant through sand supply agreements with its customers. Under these agreements, sand is typically sold at a flat rate per ton or a flat rate per ton with an index-based adjustment. The Company recognizes revenue at the point in time when the customer obtains legal title to the product, which may occur at the production facility, rail origin or at the destination terminal. Certain of the Company’s sand supply agreements contain a minimum volume commitment related to sand purchases whereby the Company charges a shortfall payment if the customer fails to meet the required minimum volume commitment. These agreements may also contain make-up provisions whereby shortfall payments can be applied in future periods against purchased volumes exceeding the minimum volume commitment. If a make-up right exists, the Company has future performance obligations to deliver excess volumes of product in subsequent periods. In accordance with ASC 606, if the customer fails to meet the minimum volume commitment, the Company will assess whether it expects the customer to fulfill its unmet commitment during the contractually specified make-up period based on discussions with the customer and management’s knowledge of the business. If the Company expects the customer will make-up deficient volumes in future periods, revenue related to shortfall payments will be deferred and recognized on the earlier of the date on which the customer utilizes make-up volumes or the likelihood that the customer will exercise its right to make-up deficient volumes becomes remote. As of December 31, 2021 and 2020, the Company had deferred revenue totaling $3.0 million and $7.9 million, respectively, related to shortfall payments. These amounts are included in accrued expenses and other current liabilities on the consolidated balance sheet. If the Company does not expect the customer will make-up deficient volumes in future periods, the breakage model will be applied and revenue related to shortfall payments will be recognized when the model indicates the customer’s inability to take delivery of excess volumes. During the years ended December 31, 2021, 2020 and 2019, the Company recognized revenue totaling $12.0 million, $24.8 million and $2.8 million, respectively, related to shortfall payments. In certain of the Company’s sand supply agreements, the customer obtains control of the product when it is loaded into rail cars and the customer reimburses the Company for all freight charges incurred. The Company has elected to account for shipping and handling as activities to fulfill the promise to transfer the sand. If revenue is recognized for the related product before the shipping and handling activities occur, the Company accrues the related costs of those shipping and handling activities. Pursuant to its contract with Gulfport, Muskie has agreed to sell and deliver specified amounts of sand to Gulfport. In September 2020, Muskie filed a lawsuit against Gulfport to recover delinquent payments due under this agreement. On November 13, 2020, Gulfport filed petitions for voluntary relief under chapter 11 of the Bankruptcy Code. On March 22, 2021, Gulfport listed the Muskie contract on its master rejection schedule filed with the bankruptcy court. The Company determined that these factors changed the scope of the contract, accelerated the duration of, and otherwise changed the rights and obligations of each party to the contract. As a result, the Company accounted for this as a contract modification during the three months ended March 31, 2021. Muskie used the expected value method to estimate unliquidated damages totaling $8.5 million, which resulted in the recognition of net revenue totaling $2.1 million and bad debt expense of $1.0 million on previously recognized revenue during the three months ended March 31, 2021. On September 21, 2021, the Company and Gulfport reached a settlement under which all litigation relating to the Muskie contract was terminated, each of the parties released all claims they had against the others with respect to the litigation matters discussed in Note 19 and Muskie’s contract claim against Gulfport was allowed under Gulfport’s plan of reorganization in the amount of $3.1 million. As a result of this settlement agreement, Muskie recognized bad debt expense of $0.2 million during the third quarter of 2021. As of December 31, 2021, Muskie had net accounts receivable due from Gulfport totaling $0.1 million, which includes a nominal amount of interest on delinquent accounts receivable. Gulfport was a related party until June 29, 2021. The revenue recognized related to this agreement is included in “product revenue - related parties” in the accompanying consolidated statement of comprehensive loss and the related accounts receivable is included in “accounts receivable, net” in the consolidated balance sheets as of December 31, 2021 and “receivables due from related parties” as of December 31, 2020. See Notes 12 and 19 below. Drilling Services Contract drilling services were provided under daywork contracts. Directional drilling services, including motor rentals, are provided on a day rate or hourly basis, and revenue is recognized as work progresses. Performance obligations are satisfied over time as the work progresses based on the measure of output. Mobilization revenue and costs were recognized over the days of actual drilling. As a result of market conditions, the Company temporarily shut down its contract land drilling operations beginning in December 2019 and its rig moving operations beginning in April 2020. Other Services During the periods presented, the Company also provided aviation, coil tubing, pressure control, flowback, cementing, acidizing, equipment rentals, crude oil hauling, full service transportation, remote accommodations and equipment manufacturing, which are reported under other services. As a result of market conditions, the Company temporarily shut down its cementing and acidizing operations as well as its flowback operations beginning in July 2019, its coil tubing, pressure control and full service transportation operations beginning in July 2020 and its crude oil hauling operations beginning in July 2021. The Company’s other services are typically provided based upon a purchase order, contract or on a spot market basis. Services are provided on a day rate, contracted or hourly basis. Performance obligations for these services are satisfied over time and revenue is recognized as the work progresses based on the measure of output. Jobs for these services are typically short-term in nature and range from a few hours to multiple days. Practical Expedients The Company does not disclose the value of unsatisfied performance obligations for (i) contracts with an original expected length of one year or less and (ii) contracts in which variable consideration is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied distinct good or service that forms part of a single performance obligation. |
Loss per Share | Loss per Share Loss per share is computed by dividing net loss by the weighted average number of outstanding shares. See Note 15. |
Equity-based and Stock-based Compensation | Equity-based Compensation The Company measures equity-based payments at fair value on the date of grant and expenses the value of these equity-based payments in compensation expense over the applicable vesting periods. See Note 16. Stock-based Compensation |
Income Taxes | Income Taxes The Company’s operations are included in a consolidated federal income tax return and other state returns. Accordingly, the Company has recognized deferred tax assets and liabilities for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases for all our subsidiaries as if each entity were a corporation, regardless of its actual characterization for U.S. federal income tax purposes. Under FASB ASC 740, Income Taxes , deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using statutory tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of deferred tax assets and liabilities as a result of a change in tax rate are recognized in the period that includes the statutory enactment date. A valuation allowance for deferred tax assets is recognized when it is more likely than not that the benefit of deferred tax assets will not be realized. To assess that likelihood, the Company uses estimates and judgments regarding future taxable income, as well as the jurisdiction in which such taxable income is generated, to determine whether a valuation allowance is required. Certain income from our infrastructure services segment and income from our remote accommodations business is subject to foreign income taxes, and such taxes are provided in the financial statements pursuant to FASB ASC 740 . |
Litigation and Contingencies | Litigation and Contingencies Accruals for litigation and contingencies are reflected in the consolidated financial statements based on management’s assessment, including advice of legal counsel, of the expected outcome of litigation or other dispute resolution proceedings and/or the expected resolution of contingencies. Liabilities for estimated losses are accrued if the potential loss from any claim or legal proceeding is considered probable and the amount can be reasonably estimated. Significant judgment is required in both the determination of probability of loss and the determination as to whether the amount is reasonably estimable. Accruals are based only on information available at the time of the assessment due to the uncertain nature of such matters. As additional information becomes available, management reassesses potential liabilities related to pending claims and litigation and may revise its previous estimates. |
Foreign Currency Translation | Foreign Currency Translation For foreign operations, assets and liabilities are translated at the period-end exchange rate and income statement items are translated at the average exchange rate for the period. Resulting translation adjustments are recorded within accumulated other comprehensive loss. Assets and liabilities denominated in foreign currencies, if any, are re-measured at the balance sheet date. Transaction gains or losses are included as a component of current period earnings. |
Environmental Matters | Environmental MattersThe Company is subject to various federal, state and local laws and regulations relating to the protection of the environment. Management has established procedures for the ongoing evaluation of the Company’s operations, to identify potential environmental exposures and to comply with regulatory policies and procedures. Environmental expenditures that relate to current operations are expensed or capitalized as appropriate. Expenditures that relate to an existing condition caused by past operations and do not contribute to current or future revenue generation are expensed as incurred. Liabilities are recorded when environmental costs are probable and the costs can be reasonably estimated. The Company maintains insurance which may cover in whole or in part certain environmental expenditures. |
Other Comprehensive Income (Loss) | Other Comprehensive LossComprehensive loss consists of net loss and other comprehensive loss. Other comprehensive loss included certain changes in equity that are excluded from net loss. Specifically, cumulative foreign currency translation adjustments are included in accumulated other comprehensive loss. |
Concentrations of Credit Risk and Significant Customers | Concentrations of Credit Risk and Significant CustomersFinancial instruments that potentially subject the Company to concentrations of credit risk consist of cash and cash equivalents in excess of federally insured limits and trade receivables. |
Recent Accounting Pronouncements | Recent Accounting Pronouncements Accounting Pronouncements Recently Adopted In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02 “Leases (Topic 842)” amending the current accounting for leases. Under the new provisions, all lessees will report a right of use asset and lease liability on the balance sheet for all leases with a term longer than one year, while maintaining substantially similar classifications for financing and operating leases. Lessor accounting remains substantially unchanged with the exception that no leases entered into after the effective date will be classified as leveraged leases. ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, and interim periods within that fiscal year. The Company adopted this ASU effective January 1, 2019 utilizing the transition method permitted by ASU No. 2018-11 “Leases (Topic 842): Targeted Improvements”, issued in August 2018, which permits an entity to recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption with no adjustment made to the comparative periods presented in the consolidated financial statements. See Note 14 for the impact the adoption of this standard had on the Company’s financial statements. In June 2018, the FASB issued ASU No. 2018-07, “Compensation - Stock Compensation (Topic 718): Improvements to Non-employee Share-Based Accounting,” which simplifies the accounting for share-based payments granted to non-employees by aligning the accounting with requirements for employee share-based compensation. Upon transition, this ASU requires non-employee awards to be measured at fair value as of the adoption date. This ASU is effective for fiscal years beginning after December 15, 2018, and interim periods within that fiscal year. The Company adopted this ASU effective January 1, 2019 and estimates the fair value of its non-employee awards (see Note 16) was approximately $18.9 million as of this date. In June 2016, the FASB issued ASU No. 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” which amends current guidance on reporting credit losses on financial instruments. This ASU requires entities to reflect its current estimate of all expected credit losses. The guidance affects most financial assets, including trade accounts receivable. This ASU is effective for fiscal years beginning after December 31, 2019, with early adoption permitted. The Company adopted this standard effective January 1, 2020. It did not have a material impact on the Company’s consolidated financial statements. |
Summary of Significant Accoun_3
Summary of Significant Accounting Policies (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Accounting Policies [Abstract] | |
Schedule of Allowance for Doubtful Accounts Receivable | Following is a roll forward of the allowance for doubtful accounts for the years ended December 31, 2021, 2020 and 2019 (in thousands): Balance, January 1, 2019 $ 5,198 Additions charged to bad debt expense 1,771 Recoveries of receivables previously charged to bad debt expense (337) Deductions for uncollectible receivables written off (1,478) Balance, December 31, 2019 5,154 Additions charged to bad debt expense 22,705 Additions charged to other selling, general and administrative expense 3,950 Additions charged to other, net - related parties 1,427 Recoveries of receivables previously charged to bad debt expense (747) Deductions for uncollectible receivables written off (2,350) Balance, December 31, 2020 30,139 Additions charged to bad debt expense 41,873 Additions charged to revenue 27,071 Additions charged to other selling, general and administrative expense 273 Additions charged to other income (expense), net - related parties 515 Additions charged to other income (expense), net 1,474 Recoveries of receivables previously charged to bad debt expense (211) Deductions for uncollectible receivables written off (83,049) Balance, December 31, 2021 $ 18,085 Balance, January 1, 2020 — Additions charged to bad debt expense 19,395 Additions charged to other selling, general and administrative expense 1,759 Additions charged to other, net - related parties 1,427 Balance, December 31, 2020 22,581 Additions charged to bad debt expense 41,196 Additions charged to revenue 27,070 Additions charged to other income (expense), net - related parties 1,842 Deductions for uncollectible receivables written off (80,975) Balance, December 31, 2021 $ 11,714 |
Schedule of Asset Retirement Obligations | Following is a roll forward of the Company’s asset retirement obligations for the years ended December 31, 2021 and 2020 (in thousands): December 31, 2021 2020 Balance as of beginning of period $ 4,746 $ 4,241 Additions and revisions of prior estimates (385) 372 Accretion expense 146 115 Liabilities settled (782) — Foreign currency translation adjustment (5) 18 Asset retirement obligation as of end of period $ 3,720 $ 4,746 |
Schedules of Significant Customers | Following is a summary of our significant customers based on accounts receivable balances at December 31, 2021 and 2020 and revenues derived for the years ended December 31, 2021, 2020 and 2019: REVENUES ACCOUNTS RECEIVABLE Years Ended December 31, At December 31, 2021 2020 2019 2021 2020 Customer A (a) — % — % 15 % 83 % 71 % Customer B (b) 7 % 16 % 20 % — % 7 % Customer C (c) 3 % 15 % — % — % 6 % a. Customer A is a third-party customer. Revenues and the related accounts receivable balances earned from Customer A were derived from the Company’s infrastructure services segment. Accounts receivable for Customer A also includes receivables due for interest charged on delinquent accounts receivable. b. Customer B was a related-party customer until June 29, 2021. Revenues earned from this customer prior to June 29, 2021 are included in services revenue - related parties and product revenue - related parties on the consolidated statements of comprehensive loss. The related accounts receivable are included in accounts receivable, net on the consolidated balance sheet at December 31, 2021 and receivables due from related parties, net at December 31, 2020. Revenues and the related accounts receivable balances earned from Customer B were derived from the Company’s well completion services segment, natural sand proppant services segment and other businesses. Accounts receivable for Customer B also included receivables due for interest charged on delinquent accounts receivable. |
Revenues (Tables)
Revenues (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Revenue from Contract with Customer [Abstract] | |
Schedule of Contract Liabilities | Following is a rollforward of the Company’s contract liabilities (in thousands): Balance, January 1, 2019 $ 4,304 Deduction for recognition of revenue (4,827) Increase for deferral of shortfall payments 8,442 Increase for deferral of customer prepayments 675 Deduction of shortfall payments due to contract renegotiations (1,350) Balance, December 31, 2019 7,244 Deduction for recognition of revenue (25,047) Increase for deferral of shortfall payments 25,436 Increase for deferral of customer prepayments 648 Balance, December 31, 2020 8,281 Deduction for recognition of revenue (12,329) Increase for deferral of shortfall payments 7,023 Increase for deferral of customer prepayments 275 Balance, December 31, 2021 $ 3,250 |
Inventories (Tables)
Inventories (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Inventory Disclosure [Abstract] | |
Schedule of Inventory | A summary of the Company’s inventories is shown below (in thousands): December 31, 2021 2020 Supplies $ 4,557 $ 6,312 Raw materials 701 613 Work in process 2,435 3,478 Finished goods 673 1,617 Total inventory $ 8,366 $ 12,020 |
Property, Plant and Equipment (
Property, Plant and Equipment (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Property, Plant and Equipment [Abstract] | |
Schedule of Property, Plant and Equipment | Property, plant and equipment include the following (in thousands): December 31, Useful Life 2021 2020 Pressure pumping equipment 3-5 years $ 220,414 $ 217,945 Drilling rigs and related equipment 3-15 years 111,478 113,146 Machinery and equipment 7-20 years 166,873 172,272 Buildings (a) 15-39 years 46,006 48,776 Vehicles, trucks and trailers 5-10 years 103,982 111,911 Coil tubing equipment 4-10 years 7,592 8,541 Land N/A 13,417 13,417 Land improvements 15 years or life of lease 10,133 10,133 Rail improvements 10-20 years 13,793 13,793 Other property and equipment (b) 3-12 years 18,235 18,640 711,923 728,574 Deposits on equipment and equipment in process of assembly (c) 3,300 3,191 715,223 731,765 Less: accumulated depreciation (d) 538,637 480,503 Total property, plant and equipment, net $ 176,586 $ 251,262 a. Included in Buildings at each of December 31, 2021 and 2020 are costs of $7.6 million related to assets under operating leases. b. Included in Other property and equipment at each of December 31, 2021 and 2020 are costs of $6.0 million related to assets under operating leases. c. Deposits on equipment and equipment in process of assembly represents deposits placed with vendors for equipment that is in the process of assembly and purchased equipment that is being outfitted for its intended use. The equipment is not yet placed in service. |
Schedule Of Depreciation, Depletion, Accretion And Amortization Expense | A summary of depreciation, depletion, amortization and accretion expense is shown below (in thousands): Years Ended December 31, 2021 2020 2019 Depreciation expense $ 76,093 $ 93,332 $ 112,435 Accretion and depletion expense 1,381 970 3,477 Amortization expense 1,001 1,015 1,121 Depreciation, depletion, amortization and accretion $ 78,475 $ 95,317 $ 117,033 |
Impairments (Tables)
Impairments (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Property, Plant and Equipment [Abstract] | |
Details of Impairment of Long-Lived Assets Held and Used by Asset | A summary of impairment of other long-lived assets is as follows (in thousands): December 31, 2021 2020 2019 Water transfer equipment $ — $ 4,203 $ — Crude oil hauling equipment — 3,275 — Coil tubing equipment — 2,160 — Flowback equipment — 1,514 — Rental equipment — 1,308 — Drilling rigs and related equipment — — 2,955 Other property, plant and equipment — 437 3,557 Intangible assets 1,212 — 846 $ 1,212 $ 12,897 $ 7,358 |
Goodwill and Intangible Assets
Goodwill and Intangible Assets (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Goodwill and Intangible Assets Disclosure [Abstract] | |
Schedule of Goodwill | Changes in the net carrying amount of goodwill by reporting segment (see Note 20) for the years ended December 31, 2021 and 2020 are presented below (in thousands): Infrastructure Well Completion Sand Other Total Balance as of January 1, 2020 Goodwill $ 891 $ 86,043 $ 2,684 $ 14,830 $ 104,448 Accumulated impairment losses — (23,423) (2,684) (10,760) (36,867) 891 62,620 — 4,070 67,581 Acquisitions — — — — — Impairment losses (a) — (53,406) — (1,567) (54,973) Balance as of December 31, 2020 Goodwill 891 86,043 2,684 14,830 104,448 Accumulated impairment losses — (76,829) (2,684) (12,327) (91,840) 891 9,214 — 2,503 12,608 Acquisitions — — — — — Impairment losses (a) (891) — — — (891) Balance as of December 31, 2021 Goodwill 891 86,043 2,684 14,830 104,448 Accumulated impairment losses (891) (76,829) (2,684) (12,327) (92,731) $ — $ 9,214 $ — $ 2,503 $ 11,717 |
Schedule of Finite-Lived Intangible Assets | The Company had the following definite lived intangible assets recorded as of the dates presented below (in thousands): December 31, 2021 2020 Customer relationships $ — $ 1,050 Trade names 7,850 9,063 Less: accumulated amortization - customer relationships — (642) Less: accumulated amortization - trade names (5,289) (4,697) Intangible assets, net $ 2,561 $ 4,774 |
Schedule of Finite-Lived Intangible Assets, Future Amortization Expense | Aggregated expected amortization expense for the future periods is expected to be as follows (in thousands): Year ended December 31: Amount 2022 $ 779 2023 779 2024 710 2025 91 2026 91 Thereafter 111 $ 2,561 |
Accrued Expenses and Other Cu_2
Accrued Expenses and Other Current Liabilities and Other Long-Term Liabilities (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Payables and Accruals [Abstract] | |
Schedule of Accrued Expense and Other Current Liabilities and Other Long-term Liabilities | Accrued expense and other current liabilities and Other long-term liabilities included the following (in thousands): December 31, 2021 2020 Accrued Expenses and Other Current Liabilities Accrued legal settlement (a) $ 18,966 $ — State and local taxes payable 13,772 13,838 Financed insurance premiums (b) 9,852 10,394 Deferred revenue 3,250 8,281 Accrued compensation and benefits 5,133 3,710 Insurance reserves 1,413 1,941 Payroll tax liability 2,810 1,816 Financing leases 1,834 1,499 Sale-leaseback liability (c) 3,340 1,290 Other 2,146 1,639 Total accrued expenses and other current liabilities $ 62,516 $ 44,408 Other Long-Term Liabilities Financing leases $ 4,375 4,618 Sale-leaseback liability (c) 7,318 3,348 Payroll tax liability — 1,977 Other — 492 Total other long-term liabilities $ 11,693 $ 10,435 a. In June 2021, the Company reached an agreement to settle a certain legal matter. See Note 19 for additional detail. b. Financed insurance premiums are due in monthly installments, are unsecured and mature within the twelve-month period following the close of the year. As of December 31, 2021, the applicable interest rates associated with financed insurance premiums ranged from 1.95% to 2.45%. As of December 31, 2020, the applicable interest rates associated with financed insurance premiums ranged from 3.45% to 3.75%. |
Debt (Tables)
Debt (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Debt Disclosure [Abstract] | |
Schedule of Debt | Long-term debt included the following (in thousands): December 31, 2021 2020 Revolving credit facility 83,370 78,000 Aviation note 3,371 4,551 Unamortized debt issuance costs (33) (48) Total debt 86,708 82,503 Less: current portion 1,468 1,165 Total long-term debt $ 85,240 $ 81,338 |
Selling, General and Administ_2
Selling, General and Administrative Expense (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Other Income and Expenses [Abstract] | |
Schedule Of Selling, General And Administrative Expense | Selling, general and administrative (“SG&A”) expense includes of the following (in thousands): Years Ended December 31, 2021 2020 2019 Cash expenses: Compensation and benefits $ 15,064 $ 14,876 $ 19,364 Professional services 11,400 19,905 17,128 Other (a) 9,052 8,828 10,300 Total cash SG&A expense 35,516 43,609 46,792 Non-cash expenses: Bad debt provision (b) 41,662 21,958 1,434 Stock based compensation 1,068 1,618 3,326 Total non-cash SG&A expense 42,730 23,576 4,760 Total SG&A expense $ 78,246 $ 67,185 $ 51,552 a. Includes travel-related costs, information technology expenses, rent, utilities and other general and administrative-related costs. b. The bad debt provision for the year ended December 31, 2021 includes $41.2 million related to the Stingray Pressure Pumping and Muskie contracts with Gulfport. The bad debt provision for the year ended December 31, 2020, included $19.4 million related to the voluntary petitions for relief filed on November 13, 2020, by Gulfport and certain of its subsidiaries. See Notes 2 and 19. |
Income Taxes (Tables)
Income Taxes (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Income Tax Disclosure [Abstract] | |
Schedule of Components of Income Tax Expense (Benefit) | The components of income tax benefit attributable to the Company for the year ended December 31, 2021, 2020 and 2019, respectively, are as follows (in thousands): Year Ended December 31, 2021 2020 2019 U.S. current income tax expense (benefit) $ 290 $ (6,931) $ 386 U.S. deferred income tax benefit (23,740) (12,330) (21,761) Foreign current income tax expense 8,852 6,948 30,172 Foreign deferred income tax (benefit) expense (8,265) 144 (20,878) Total $ (22,863) $ (12,169) $ (12,081) |
Schedule of Effective Income Tax Rate Reconciliation | A reconciliation of the statutory federal income tax amount to the recorded expense is as follows (in thousands): Year Ended December 31, 2021 2020 2019 Loss before income taxes $ (124,293) $ (119,776) $ (91,125) Statutory income tax rate 21 % 21 % 21 % Expected income tax (benefit) expense (26,102) (25,153) (19,136) Change in tax rate — (161) — Change in uncertain tax positions 1,043 — — Foreign income tax rate differential (282) 2,556 9,387 Foreign (loss) earnings not in reported income (336) 3,252 12,581 Foreign tax credits (7,749) (7,133) (26,141) Withholding taxes (49) 1,019 3,635 Goodwill impairment 52 11,544 6,506 Other permanent differences 426 1,290 1,873 State tax expenses (2,449) (1,664) 2,364 CARES act — (2,378) — Return to provision 390 894 (15,156) Change in valuation allowance 12,193 3,765 12,006 Total $ (22,863) $ (12,169) $ (12,081) |
Schedule of Deferred Tax Assets and Liabilities | Deferred tax liabilities attributable to the Company consisted of the following (in thousands): Year Ended December 31, 2021 2020 Deferred tax assets: Allowance for doubtful accounts $ 1,241 $ 1,541 Lease asset 4,432 6,060 Intangible assets 1,070 — Accrued liabilities 12,833 740 Net operating loss carryover 13,447 613 Foreign tax credits 83,780 80,615 Other 1,652 1,919 Valuation allowance (71,612) (67,888) Deferred tax assets 46,843 23,600 Deferred tax liabilities: Property and equipment $ (28,126) $ (39,057) Intangible assets — (450) Lease liability (4,392) (6,030) Other (7,096) (2,804) Deferred tax liabilities (39,614) (48,341) Net deferred tax asset (liability) $ 7,229 $ (24,741) Reflected in accompanying balance sheet as: Deferred income tax asset $ 8,094 $ — Deferred income tax liability (865) (24,741) Total $ 7,229 $ (24,741) |
Summary of Uncertain Tax Positions | A reconciliation of the beginning and ending amounts of liabilities associated with uncertain tax positions for the year ended December 31, 2021 is as follows ($ in thousands): Balance, January 1, 2021 $ — Additions for tax positions of prior years 1,043 Balance, December 31, 2021 $ 1,043 |
Leases (Tables)
Leases (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Leases [Abstract] | |
Schedule of Lease Expense and Other Supplemental Information | Lease expense consisted of the following for the years ended December 31, 2021 and 2020 (in thousands): Year Ended December 31, 2021 2020 Operating lease expense $ 9,156 $ 13,735 Short-term lease expense 335 812 Finance lease expense: Amortization of right-of-use assets 1,582 1,311 Interest on lease liabilities 202 203 Total lease expense $ 11,275 $ 16,061 Other supplemental information related to leases for the years ended December 31, 2021 and 2020 is as follows (in thousands): Year Ended December 31, 2021 2020 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 9,284 $ 13,643 Operating cash flows from finance leases 202 203 Financing cash flows from finance leases 1,677 1,318 Right-of-use assets obtained in exchange for lease obligations: Operating leases $ 594 $ (10,260) Finance leases 1,750 2,431 ` Year Ended December 31, 2021 2020 Weighted-average remaining lease term: Operating leases 3.1 years 3.2 years Finance leases 3.3 years 4.2 years Weighted-average discount rate: Operating leases 3.3 % 3.5 % Finance leases 3.3 % 3.5 % |
Schedule of Lease Assets and Liabilities | Supplemental balance sheet information related to leases as of December 31, 2021 and 2020 is as follows (in thousands): Year Ended December 31, 2021 2020 Operating leases: Operating lease right-of-use assets $ 12,168 $ 20,179 Current operating lease liability 5,942 8,618 Long-term operating lease liability 5,918 11,377 Finance leases: Property and equipment, net $ 6,065 $ 6,065 Accrued expenses and other current liabilities 1,834 1,499 Other liabilities 4,375 4,618 |
Schedule of Finance Lease Liabilities | Maturities of lease liabilities as of December 31, 2021 are as follows (in thousands): Operating Leases Finance Leases 2022 $ 6,214 $ 2,005 2023 3,600 2,261 2024 1,641 965 2025 517 524 2026 147 795 Thereafter 407 — Total lease payments 12,526 6,550 Less: Present value discount 666 341 Present value of lease payments $ 11,860 $ 6,209 |
Schedule of Operating Lease Liabilities | Maturities of lease liabilities as of December 31, 2021 are as follows (in thousands): Operating Leases Finance Leases 2022 $ 6,214 $ 2,005 2023 3,600 2,261 2024 1,641 965 2025 517 524 2026 147 795 Thereafter 407 — Total lease payments 12,526 6,550 Less: Present value discount 666 341 Present value of lease payments $ 11,860 $ 6,209 |
Dividends and Earnings (Loss)_2
Dividends and Earnings (Loss) Per Share (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Earnings Per Share [Abstract] | |
Schedule of Dividends Paid | The table below summarizes the dividends paid on the Company’s common stock. Per Share Total (in thousands) 2019 Paid on February 14, 2019 $ 0.125 $ 5,609 Paid on May 17, 2019 0.125 5,610 Total cash dividends $ 0.25 $ 11,219 |
Schedule of Earnings Per Unit and Per Share | Earnings (Loss) Per Share Year Ended December 31, 2021 2020 2019 (in thousands, except per share data) Basic loss per share: Allocation of earnings: Net loss $ (101,430) $ (107,607) $ (79,044) Weighted average common shares outstanding 46,428 45,644 45,011 Basic loss per share $ (2.18) $ (2.36) $ (1.76) Diluted loss per share: Allocation of earnings: Net loss $ (101,430) $ (107,607) $ (79,044) Weighted average common shares, including dilutive effect (a) 46,428 45,644 45,011 Diluted loss per share $ (2.18) $ (2.36) $ (1.76) |
Stock-Based Compensation (Table
Stock-Based Compensation (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Share-based Payment Arrangement [Abstract] | |
Stock-Based Compensation | A summary of the status and changes of the unvested shares of restricted stock under the 2016 Plan is presented below. Number of Unvested Restricted Stock Units Weighted Average Grant-Date Fair Value Unvested restricted stock units as of January 1, 2019 434,119 $ 22.78 Granted 101,181 6.83 Vested (231,896) 22.45 Forfeited (82,163) 18.55 Unvested restricted stock units as of December 31, 2019 221,241 22.43 Granted 2,401,446 0.98 Vested (660,738) 5.32 Forfeited (47,167) 3.28 Unvested restricted stock units as of December 31, 2020 1,914,782 1.21 Granted 128,205 3.90 Vested (914,782) 1.52 Forfeited — — Unvested restricted stock units as of December 31, 2021 1,128,205 1.27 |
Related Party Transactions (Tab
Related Party Transactions (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Related Party Transactions [Abstract] | |
Schedule of Related Party Transactions | Following is a summary of related party transactions (in thousands): Years Ended December 31, At December 31, 2021 2020 2019 2021 2020 REVENUES ACCOUNTS RECEIVABLE Stingray Pressure Pumping and Gulfport (a) $ 14,812 $ 42,460 $ 90,357 $ — $ 25,429 Muskie and Gulfport (b) 2,145 7,500 27,689 — 1,127 SR Energy and Gulfport (c) — 113 8,772 — 8 Aquahawk and Gulfport (d) — — 828 — — Cobra Aviation/ARS/Leopard and Brim Equipment (e) 371 446 2,093 85 44 Panther and El Toro (f) 599 38 573 — — Other Relationships 12 34 1 3 9 $ 17,939 $ 50,591 $ 130,313 $ 88 $ 26,617 OTHER ACCOUNTS RECEIVABLE Stingray Pressure Pumping and Gulfport (a) $ 514 $ 1,887 $ — $ — $ 1,841 Muskie and Gulfport (b) 1 3 — — 3 $ 515 $ 1,890 $ — $ — $ 1,844 $ 88 $ 28,461 a. Stingray Pressure Pumping provided pressure pumping, stimulation and related completion services to Gulfport. Other amount represents interest charged on delinquent accounts receivable related to these services. On June 29, 2021, Gulfport ceased to be a related party. See Note 3. b. Muskie agreed to sell and deliver, and Gulfport has agreed to purchase, specified annual and monthly amounts of natural sand proppant, subject to certain exceptions specified in the agreement, and pay certain costs and expenses. Other amount represents interest charged on delinquent accounts receivable related to this agreement. On June 29, 2021, Gulfport ceased to be a related party. See Note 3. c. SR Energy provided rental services for Gulfport. On June 29, 2021, Gulfport ceased to be a related party. d. Aquahawk provided water transfer services for Gulfport pursuant to a master services agreement. e. Cobra Aviation, ARS and Leopard lease helicopters to Brim Equipment pursuant to aircraft lease and management agreements. f. Panther provides directional drilling services for El Toro, an affiliate of Wexford, pursuant to a master service agreement. COST OF REVENUE ACCOUNTS PAYABLE Years Ended December 31, At December 31, 2021 2020 2019 2021 2020 Cobra Aviation/ARS/Leopard and Brim Equipment (a) 73 72 4,720 5 1 The Company and Caliber (b) 351 248 — — — Other Relationships 107 98 50 — — $ 531 $ 418 $ 4,770 $ 5 $ 1 SELLING, GENERAL AND ADMINISTRATIVE COSTS The Company and Wexford (c) 5 3 650 — 2 The Company and Caliber (b) 374 774 785 — — Cobra Aviation/ARS/Leopard and Brim Equipment (a) — — 233 — Other Relationships 8 (19) 179 — — $ 387 $ 758 $ 1,847 $ — $ 2 CAPITAL EXPENDITURES Leopard and Brim Equipment (a) — — 420 — — $ — $ — $ 420 $ — $ — $ 5 $ 3 a. Cobra Aviation, ARS and Leopard lease helicopters to Brim Equipment pursuant to aircraft lease and management agreements. b. Caliber, an entity controlled by Wexford, leases office space to the Company. c. Wexford provides certain administrative and analytical services to the Company and, from time to time, the Company pays for goods and services on behalf of Wexford. |
Commitments and Contingencies (
Commitments and Contingencies (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Commitments and Contingencies Disclosure [Abstract] | |
Schedule Of Letters Of Credit | The letters of credit are categorized below (in thousands): December 31, 2021 2020 Bonding program $ 1,000 $ 5,000 Environmental remediation 3,694 3,694 Insurance programs 3,890 3,890 Rail car commitments 455 455 Total letters of credit $ 9,039 $ 13,039 |
Reporting Segments and Geogra_2
Reporting Segments and Geographic Areas (Tables) | 12 Months Ended |
Dec. 31, 2021 | |
Segment Reporting [Abstract] | |
Segment Reporting Information, by Segment | The following tables set forth certain financial information with respect to the Company’s reportable segments (in thousands): Year Ended December 31, 2021 Infrastructure Well Completion Sand Drilling All Other Eliminations Total Revenue from external customers $ 93,403 $ 84,190 $ 30,880 $ 4,197 $ 16,292 $ — $ 228,962 Intersegment revenues — 144 3,980 124 2,218 (6,466) — Total revenue 93,403 84,334 34,860 4,321 18,510 (6,466) 228,962 Cost of revenue, exclusive of depreciation, depletion, amortization and accretion 90,363 58,782 27,232 6,102 15,847 — 198,326 Intersegment cost of revenues 196 5,770 — — 500 (6,466) — Total cost of revenue 90,559 64,552 27,232 6,102 16,347 (6,466) 198,326 Selling, general and administrative 18,267 49,275 5,351 1,414 3,939 — 78,246 Depreciation, depletion, amortization and accretion 21,880 26,377 9,005 7,996 13,217 — 78,475 Impairment of goodwill 891 — — — — — 891 Impairment of other long-lived assets 665 — — — 547 — 1,212 Operating loss (38,859) (55,870) (6,728) (11,191) (15,540) — (128,188) Interest expense 3,925 1,107 474 293 607 — 6,406 Other (income) expense, net (6,785) 1,073 (874) (177) (3,538) — (10,301) Loss before income taxes $ (35,999) $ (58,050) $ (6,328) $ (11,307) $ (12,609) $ — $ (124,293) Total expenditures for property, plant and equipment $ 627 $ 4,327 $ 484 $ 44 $ 361 $ — $ 5,843 As of December 31, 2021: Intangible assets, net $ 165 $ 1,995 $ — $ — $ 401 $ — $ 2,561 Total assets $ 427,626 $ 56,036 $ 156,519 $ 27,457 $ 129,202 $ (75,948) $ 720,892 Year Ended December 31, 2020 Infrastructure Well Completion Sand Drilling All Other Eliminations Total Revenue from external customers $ 157,751 $ 87,201 $ 34,265 $ 7,746 $ 26,113 $ — $ 313,076 Intersegment revenue — 1,124 95 39 2,716 (3,974) — Total revenue 157,751 88,325 34,360 7,785 28,829 (3,974) 313,076 Cost of revenue, exclusive of depreciation, depletion, amortization and accretion 124,232 45,647 25,955 10,757 25,430 — 232,021 Intersegment cost of revenues 323 1,836 — 152 1,663 (3,974) — Total cost of revenue 124,555 47,483 25,955 10,909 27,093 (3,974) 232,021 Selling, general and administrative 27,261 23,039 7,807 3,149 5,929 — 67,185 Depreciation, depletion, amortization and accretion 29,373 30,411 9,771 10,039 15,723 — 95,317 Impairment of goodwill — 53,406 — — 1,567 — 54,973 Impairment of other long-lived assets — 4,203 — 326 8,368 — 12,897 Operating loss (23,438) (70,217) (9,173) (16,638) (29,851) — (149,317) Interest expense 2,794 1,130 312 454 707 — 5,397 Other (income) expense, net (32,437) (2,274) 1,839 (227) (1,839) — (34,938) Income (loss) before income taxes $ 6,205 $ (69,073) $ (11,324) $ (16,865) $ (28,719) $ — $ (119,776) Total expenditures for property, plant and equipment $ 258 $ 4,358 $ 1,073 $ 432 $ 716 $ — $ 6,837 As of December 31, 2020: Intangible assets, net $ 1,063 $ 2,683 $ — $ — $ 1,028 $ — $ 4,774 Total assets $ 437,296 $ 99,247 $ 172,927 $ 36,252 $ 136,422 $ (57,582) $ 824,562 Year Ended December 31, 2019 Infrastructure Well Completion Sand Drilling All Other Eliminations Total Revenue from external customers $ 210,712 $ 241,951 $ 67,267 $ 31,728 $ 73,354 $ — $ 625,012 Intersegment revenues 2,573 1,851 29,796 236 15,232 (49,688) — Total revenue 213,285 243,802 97,063 31,964 88,586 (49,688) 625,012 Cost of revenue, exclusive of depreciation, depletion, amortization and accretion 160,731 174,816 87,637 35,925 84,679 — 543,788 Intersegment cost of revenues 12,820 31,727 15 1,028 4,158 (49,748) — Total cost of revenue 173,551 206,543 87,652 36,953 88,837 (49,748) 543,788 Selling, general and administrative 23,616 10,889 5,006 4,177 7,864 — 51,552 Depreciation, depletion, amortization and accretion 30,349 40,159 14,050 13,143 19,332 — 117,033 Impairment of goodwill — 23,423 2,684 — 7,557 — 33,664 Impairment of other long-lived assets — — — 2,955 4,403 — 7,358 Operating loss (14,231) (37,212) (12,329) (25,264) (39,407) 60 (128,383) Interest expense 1,674 1,228 193 862 1,001 — 4,958 Other expense (41,949) 580 67 (9) (905) — (42,216) (Loss) income before income taxes $ 26,044 $ (39,020) $ (12,589) $ (26,117) $ (39,503) $ 60 $ (91,125) Total expenditures for property, plant and equipment $ 3,456 $ 14,703 $ 2,877 $ 3,156 $ 11,569 $ — 35,761 As of December 31, 2019: Intangible assets, net $ 1,296 $ 3,371 $ — $ — $ 1,121 $ — $ 5,788 Total assets $ 420,755 $ 172,608 $ 189,415 $ 55,273 $ 166,406 $ (52,072) $ 952,385 |
Revenue by Country | The following table presents consolidated revenues by country based on sales destination of the products or services (in thousands): Year Ended December 31, 2021 2020 2019 United States $ 217,958 $ 302,205 $ 516,276 Puerto Rico — 53 96,630 Canada 10,685 10,723 11,946 Other 319 95 160 Total $ 228,962 $ 313,076 $ 625,012 |
Long-lived Assets by Country | The following table presents long-lived assets, excluding deferred income tax assets, by country (in thousands): Year Ended December 31, 2021 2020 2019 United States $ 258,666 $ 342,838 $ 526,584 Canada 13,349 16,976 18,821 Total $ 272,015 $ 359,814 $ 545,405 |
Summary of Significant Accoun_4
Summary of Significant Accounting Policies - Reclassifications (Details) $ in Millions | 12 Months Ended |
Dec. 31, 2021USD ($) | |
Other, net | Legal Expense Reclassification For Expenses Unrelated To Ongoing Operations | |
Reclassification [Line Items] | |
Legal expenses | $ 5.4 |
Summary of Significant Accoun_5
Summary of Significant Accounting Policies - Cash and Cash Equivalents (Details) $ in Millions | Dec. 31, 2021CAD ($) |
Accounting Policies [Abstract] | |
Cash | $ 1.5 |
Summary of Significant Accoun_6
Summary of Significant Accounting Policies - Account Receivable Narrative (Details) $ in Thousands | Mar. 25, 2020USD ($) | Dec. 31, 2021USD ($) | Dec. 31, 2020USD ($) | Dec. 31, 2019USD ($) | May 26, 2021USD ($)contractComplianceIssue | Nov. 13, 2020USD ($) |
Business Acquisition [Line Items] | ||||||
Allowance for doubtful accounts, period increase | $ 700 | $ 3,300 | $ 1,800 | |||
Receivables from related parties, net | 88 | 28,461 | ||||
Recovery amount in undisputed claims | $ 61,700 | |||||
Number of FEMA contract compliance issues raised | contractComplianceIssue | 2 | |||||
Insurance Claims | ||||||
Business Acquisition [Line Items] | ||||||
Allowance for doubtful accounts, period increase | 300 | |||||
Puerto Rico Electric Power Authority (PREPA) | ||||||
Business Acquisition [Line Items] | ||||||
Interest income, other | 36,600 | 32,200 | $ 42,000 | |||
Interest charged on accounts receivable | 110,800 | 74,300 | ||||
Accounts receivable, contract costs, amount expected to be authorized | $ 47,000 | |||||
Puerto Rico Electric Power Authority (PREPA) | Revolving Credit Facility | Cobra Acquisitions | ||||||
Business Acquisition [Line Items] | ||||||
Debt instrument, payment pending from third party | 337,800 | 301,200 | ||||
Gulfport | ||||||
Business Acquisition [Line Items] | ||||||
Interest charged on accounts receivable | $ 1,400 | $ 3,300 | ||||
Receivables from related parties, net | $ 100 |
Summary of Significant Accoun_7
Summary of Significant Accounting Policies - Accounts Receivable (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Accounts, Notes, Loans and Financing Receivable [Line Items] | |||
Beginning balance | $ 30,139 | $ 5,154 | $ 5,198 |
Additions charged to bad debt expense | 41,873 | 22,705 | 1,771 |
Additions charged to revenue | 27,071 | ||
Additions charged to other selling, general and administrative expense | 273 | 3,950 | |
Additions charged to other income (expense), net - related parties | 515 | 1,427 | |
Additions charged to other income (expense), net | 1,474 | ||
Recoveries of receivables previously charged to bad debt expense | (211) | (747) | (337) |
Deductions for uncollectible receivables written off | (83,049) | (2,350) | (1,478) |
Ending balance | 18,085 | 30,139 | 5,154 |
Gulfport | |||
Accounts, Notes, Loans and Financing Receivable [Line Items] | |||
Beginning balance | 22,581 | 0 | |
Additions charged to bad debt expense | 41,196 | 19,395 | |
Additions charged to revenue | 27,070 | ||
Additions charged to other selling, general and administrative expense | 1,759 | ||
Additions charged to other income (expense), net - related parties | 1,842 | 1,427 | |
Deductions for uncollectible receivables written off | (80,975) | ||
Ending balance | $ 11,714 | $ 22,581 | $ 0 |
Summary of Significant Accoun_8
Summary of Significant Accounting Policies - Inventory (Details) - USD ($) | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Property, Plant and Equipment [Line Items] | |||
Amortization of coil tubing strings | $ 0 | $ 359,000 | $ 1,641,000 |
Coil Tubing Strings | |||
Property, Plant and Equipment [Line Items] | |||
Inventory useful life (no longer than) | 12 months |
Summary of Significant Accoun_9
Summary of Significant Accounting Policies - Assets Retirement Obligations (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2021 | Dec. 31, 2020 | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||
Balance as of beginning of period | $ 4,746 | $ 4,241 |
Additions and revisions of prior estimates | (385) | 372 |
Accretion expense | 146 | 115 |
Liabilities settled | (782) | 0 |
Foreign currency translation adjustment | (5) | 18 |
Asset retirement obligation as of end of period | $ 3,720 | $ 4,746 |
Summary of Significant Accou_10
Summary of Significant Accounting Policies - Revenue Recognition (Details) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||
Accounts receivable, net | $ 407,550 | $ 393,112 |
Deferred revenue | 3,250 | 8,281 |
Unbilled Revenues | ||
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||
Accounts receivable, net | $ 22,000 | 32,300 |
Accounts receivable, related parties | $ 1,500 |
Summary of Significant Accou_11
Summary of Significant Accounting Policies - Income Taxes (Details) $ in Thousands | 12 Months Ended |
Dec. 31, 2021USD ($) | |
Accounting Policies [Abstract] | |
Additions for tax positions of prior years | $ 1,043 |
Summary of Significant Accou_12
Summary of Significant Accounting Policies - Concentration of Credit Risk and Significant Customers (Details) - Customer Concentration Risk | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Customer A | REVENUES | |||
Concentration Risk [Line Items] | |||
Concentration risk, percentage | 0.00% | 0.00% | 15.00% |
Customer A | ACCOUNTS RECEIVABLE | |||
Concentration Risk [Line Items] | |||
Concentration risk, percentage | 83.00% | 71.00% | |
Customer B | REVENUES | |||
Concentration Risk [Line Items] | |||
Concentration risk, percentage | 7.00% | 16.00% | 20.00% |
Customer B | ACCOUNTS RECEIVABLE | |||
Concentration Risk [Line Items] | |||
Concentration risk, percentage | 0.00% | 7.00% | |
Customer C | REVENUES | |||
Concentration Risk [Line Items] | |||
Concentration risk, percentage | 3.00% | 15.00% | 0.00% |
Customer C | ACCOUNTS RECEIVABLE | |||
Concentration Risk [Line Items] | |||
Concentration risk, percentage | 0.00% | 6.00% |
Summary of Significant Accou_13
Summary of Significant Accounting Policies - New Accounting Guidance (Details) $ in Millions | Jan. 01, 2019USD ($) |
Non-Employees Member | Accounting Standards Update 2018-07 | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
Compensation expense | $ 18.9 |
Revenues - Narrative (Details)
Revenues - Narrative (Details) - USD ($) | 3 Months Ended | 12 Months Ended | ||||||
Sep. 30, 2021 | Mar. 31, 2021 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | Sep. 21, 2021 | Nov. 13, 2020 | Dec. 31, 2018 | |
Disaggregation of Revenue [Line Items] | ||||||||
Bad debt expense | $ 41,662,000 | $ 21,958,000 | $ 1,434,000 | |||||
Deferred revenue related to shortfall payments | 3,250,000 | 8,281,000 | 7,244,000 | $ 4,304,000 | ||||
Revenue recognized net of customer prepayment deferrals | 12,000,000 | 24,800,000 | 2,800,000 | |||||
Contract assets | 0 | 0 | $ 0 | |||||
Gulfport | ||||||||
Disaggregation of Revenue [Line Items] | ||||||||
Unliquidated damages | $ 46,400,000 | |||||||
Bad debt expense | 3,800,000 | |||||||
Due from related parties | 19,400,000 | $ 46,900,000 | ||||||
Stingray Pressure Pumping | Gulfport | ||||||||
Disaggregation of Revenue [Line Items] | ||||||||
Unliquidated damages | 37,900,000 | |||||||
Recognized revenue | 14,800,000 | |||||||
Bad debt expense | $ 31,000,000 | 2,900,000 | ||||||
Other expenses | 1,300,000 | |||||||
Muskie Proppant LLC | Gulfport | ||||||||
Disaggregation of Revenue [Line Items] | ||||||||
Unliquidated damages | 8,500,000 | |||||||
Bad debt expense | 1,000,000 | |||||||
Revenue recognized related to shortfall payments | $ 2,100,000 | |||||||
Due from related parties | 100,000 | |||||||
Muskie and Gulfport | Gulfport | ||||||||
Disaggregation of Revenue [Line Items] | ||||||||
Bad debt expense | $ 200,000 | |||||||
General unsecured claim | $ 3,100,000 | |||||||
Shortfall Payments | ||||||||
Disaggregation of Revenue [Line Items] | ||||||||
Deferred revenue related to shortfall payments | $ 3,000,000 | $ 7,900,000 |
Revenues - Schedule of Contract
Revenues - Schedule of Contract Liabilities (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Contract with Customer, Liability [Roll Forward] | |||
Balance at beginning of period | $ 8,281 | $ 7,244 | $ 4,304 |
Deduction for recognition of revenue | (12,329) | (25,047) | (4,827) |
Increase for deferral of shortfall payments | 7,023 | 25,436 | 8,442 |
Increase for deferral of customer prepayments | 275 | 648 | 675 |
Deduction of shortfall payments due to contract renegotiations | (1,350) | ||
Balance at end of period | $ 3,250 | $ 8,281 | $ 7,244 |
Revenues - Performance Obligati
Revenues - Performance Obligations (Details) $ in Millions | Dec. 31, 2021USD ($) |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Unsatisfied performance obligations | $ 1.7 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Performance obligation, timing of satisfaction period | 6 months |
Inventory (Details)
Inventory (Details) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Inventory Disclosure [Abstract] | ||
Supplies | $ 4,557 | $ 6,312 |
Raw materials | 701 | 613 |
Work in process | 2,435 | 3,478 |
Finished goods | 673 | 1,617 |
Total inventory | $ 8,366 | $ 12,020 |
Property, Plant and Equipment -
Property, Plant and Equipment - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 711,923 | $ 728,574 | |
Deposits on equipment and equipment in process of assembly | 3,300 | 3,191 | |
Total property, plant and equipment, net | 176,586 | 251,262 | |
Accumulated depreciation of assets under operating leases, lessor | 6,600 | 5,000 | |
Proceeds from disposal of property and equipment | 11,350 | 6,782 | $ 3,217 |
Gain (loss) on disposal of property and equipment | 5,435 | 1,379 | (55) |
Pressure pumping equipment | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 220,414 | 217,945 | |
Pressure pumping equipment | Minimum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 3 years | ||
Pressure pumping equipment | Maximum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 5 years | ||
Drilling rigs and related equipment | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 111,478 | 113,146 | |
Proceeds from disposal of property and equipment | 300 | 700 | |
Gain (loss) on disposal of property and equipment | $ 300 | 700 | |
Drilling rigs and related equipment | Minimum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 3 years | ||
Drilling rigs and related equipment | Maximum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 15 years | ||
Machinery and equipment | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 166,873 | 172,272 | |
Machinery and equipment | Minimum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 7 years | ||
Machinery and equipment | Maximum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 20 years | ||
Buildings | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 46,006 | 48,776 | |
Assets under operating leases, lessor | $ 7,600 | 7,600 | |
Buildings | Minimum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 15 years | ||
Buildings | Maximum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 39 years | ||
Vehicles, trucks and trailers | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 103,982 | 111,911 | |
Vehicles, trucks and trailers | Minimum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 5 years | ||
Vehicles, trucks and trailers | Maximum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 10 years | ||
Coil tubing equipment | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 7,592 | 8,541 | |
Coil tubing equipment | Minimum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 4 years | ||
Coil tubing equipment | Maximum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 10 years | ||
Land | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 13,417 | 13,417 | |
Land improvements | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 10,133 | 10,133 | |
Land improvements | Minimum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 15 years | ||
Rail improvements | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 13,793 | 13,793 | |
Rail improvements | Minimum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 10 years | ||
Rail improvements | Maximum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 20 years | ||
Other property and equipment | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment | $ 18,235 | 18,640 | |
Assets under operating leases, lessor | $ 6,000 | 6,000 | |
Other property and equipment | Minimum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 3 years | ||
Other property and equipment | Maximum | |||
Property, Plant and Equipment [Line Items] | |||
Useful Life | 12 years | ||
Assets Held And Used | |||
Property, Plant and Equipment [Line Items] | |||
Property, plant and equipment, gross | $ 715,223 | 731,765 | |
Less: accumulated depreciation | 538,637 | 480,503 | |
Total property, plant and equipment, net | 176,586 | 251,262 | |
Comprehensive Income | |||
Property, Plant and Equipment [Line Items] | |||
Proceeds from disposal of property and equipment | 11,200 | 6,100 | 3,200 |
Gain (loss) on disposal of property and equipment | $ 5,100 | $ 700 | $ (100) |
Property, Plant and Equipment_2
Property, Plant and Equipment - Schedule of Depreciation, Amortization, Accretion, and Depletion (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Property, Plant and Equipment [Abstract] | |||
Depreciation expense | $ 76,093 | $ 93,332 | $ 112,435 |
Accretion and depletion expense | 1,381 | 970 | 3,477 |
Amortization expense | 1,001 | 1,015 | 1,121 |
Depreciation, depletion, amortization and accretion | $ 78,475 | $ 95,317 | $ 117,033 |
Impairments (Details)
Impairments (Details) - USD ($) $ in Thousands | 3 Months Ended | 12 Months Ended | |||||
Dec. 31, 2021 | Mar. 31, 2020 | Dec. 31, 2019 | Sep. 30, 2019 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Property, Plant and Equipment [Line Items] | |||||||
Impairment of goodwill | $ 55,000 | $ 30,500 | $ 3,200 | $ 891 | $ 54,973 | $ 33,664 | |
Intangible assets | 1,212 | 0 | 846 | ||||
Impairment of long-lived assets | $ 12,900 | 1,212 | 12,897 | 7,358 | |||
Water transfer equipment | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Asset impairment charges | 0 | 4,203 | 0 | ||||
Crude oil hauling equipment | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Asset impairment charges | 0 | 3,275 | 0 | ||||
Coil tubing equipment | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Asset impairment charges | 0 | 2,160 | 0 | ||||
Flowback equipment | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Asset impairment charges | 0 | 1,514 | 0 | ||||
Rental equipment | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Asset impairment charges | 0 | 1,308 | 0 | ||||
Drilling rigs and related equipment | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Asset impairment charges | 0 | 0 | 2,955 | ||||
Other property, plant and equipment | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Asset impairment charges | 0 | $ 437 | 3,557 | ||||
Trade names | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Impairment of long-lived assets | 500 | ||||||
Trade Names and Customer Relationships | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Impairment of long-lived assets | 700 | ||||||
Customer relationships | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Impairment of finite lived intangible assets | $ 100 | $ 800 | |||||
Five Star and Higher Power | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Impairment of goodwill | $ 900 | ||||||
Higher Power | Trade Names and Customer Relationships | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Impairment of long-lived assets | $ 1,200 |
Goodwill and Intangible Asset_2
Goodwill and Intangible Assets - Schedule Of Changes in Goodwill (Details) - USD ($) $ in Thousands | 3 Months Ended | 12 Months Ended | ||||
Mar. 31, 2020 | Dec. 31, 2019 | Sep. 30, 2019 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Goodwill [Roll Forward] | ||||||
Goodwill, gross period start | $ 104,448 | $ 104,448 | $ 104,448 | |||
Accumulated impairment losses | $ (36,867) | (92,731) | (91,840) | $ (36,867) | ||
Goodwill | 67,581 | 11,717 | 12,608 | 67,581 | ||
Acquisitions | 0 | 0 | ||||
Impairment losses | (55,000) | (30,500) | $ (3,200) | (891) | (54,973) | (33,664) |
Goodwill, gross period end | 104,448 | 104,448 | 104,448 | 104,448 | ||
Infrastructure | ||||||
Goodwill [Roll Forward] | ||||||
Goodwill, gross period start | 891 | 891 | 891 | |||
Accumulated impairment losses | 0 | (891) | 0 | 0 | ||
Goodwill | 891 | 0 | 891 | 891 | ||
Acquisitions | 0 | 0 | ||||
Impairment losses | (891) | 0 | ||||
Goodwill, gross period end | 891 | 891 | 891 | 891 | ||
Well Completion | ||||||
Goodwill [Roll Forward] | ||||||
Goodwill, gross period start | 86,043 | 86,043 | 86,043 | |||
Accumulated impairment losses | (23,423) | (76,829) | (76,829) | (23,423) | ||
Goodwill | 62,620 | 9,214 | 9,214 | 62,620 | ||
Acquisitions | 0 | 0 | ||||
Impairment losses | 0 | (53,406) | ||||
Goodwill, gross period end | 86,043 | 86,043 | 86,043 | 86,043 | ||
Sand | ||||||
Goodwill [Roll Forward] | ||||||
Goodwill, gross period start | 2,684 | 2,684 | 2,684 | |||
Accumulated impairment losses | (2,684) | (2,684) | (2,684) | (2,684) | ||
Goodwill | 0 | 0 | 0 | 0 | ||
Acquisitions | 0 | 0 | ||||
Impairment losses | 0 | 0 | ||||
Goodwill, gross period end | 2,684 | 2,684 | 2,684 | 2,684 | ||
Other | ||||||
Goodwill [Roll Forward] | ||||||
Goodwill, gross period start | $ 14,830 | 14,830 | 14,830 | |||
Accumulated impairment losses | (10,760) | (12,327) | (12,327) | (10,760) | ||
Goodwill | 4,070 | 2,503 | 2,503 | 4,070 | ||
Acquisitions | 0 | 0 | ||||
Impairment losses | 0 | (1,567) | ||||
Goodwill, gross period end | $ 14,830 | $ 14,830 | $ 14,830 | $ 14,830 |
Goodwill and Intangible Asset_3
Goodwill and Intangible Assets - Definite Lived Intangible Assets (Details) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 |
Finite-Lived Intangible Assets [Line Items] | |||
Intangible assets, net | $ 2,561 | $ 4,774 | $ 5,788 |
Customer relationships | |||
Finite-Lived Intangible Assets [Line Items] | |||
Finite-lived intangible assets, gross | 0 | 1,050 | |
Less: accumulated amortization | 0 | (642) | |
Trade names | |||
Finite-Lived Intangible Assets [Line Items] | |||
Finite-lived intangible assets, gross | 7,850 | 9,063 | |
Less: accumulated amortization | $ (5,289) | $ (4,697) |
Goodwill and Intangible Asset_4
Goodwill and Intangible Assets - Narrative (Details) - USD ($) $ in Thousands | 3 Months Ended | 12 Months Ended | ||
Sep. 30, 2019 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Finite-Lived Intangible Assets [Line Items] | ||||
Amortization of intangible assets | $ 1,001 | $ 1,015 | $ 1,121 | |
Customer relationships | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Impairment of finite lived intangible assets | $ 100 | 800 | ||
Customer relationships | WTL Oil LLC | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Impairment of finite lived intangible assets | $ 800 | |||
Trade names | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired finite-lived intangible assets, weighted average useful life (in years) | 3 years 11 months 12 days | |||
Minimum | Trade names | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Finite-lived intangible asset, useful life (in years) | 10 years | |||
Maximum | Trade names | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Finite-lived intangible asset, useful life (in years) | 20 years |
Goodwill and Intangible Asset_5
Goodwill and Intangible Assets - Aggregated Expected Amortization Expense (Details) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 |
Goodwill and Intangible Assets Disclosure [Abstract] | |||
2022 | $ 779 | ||
2023 | 779 | ||
2024 | 710 | ||
2025 | 91 | ||
2026 | 91 | ||
Thereafter | 111 | ||
Intangible assets, net | $ 2,561 | $ 4,774 | $ 5,788 |
Equity Method Investment (Detai
Equity Method Investment (Details) | Dec. 21, 2018USD ($)helicopter | Dec. 31, 2021USD ($) | Dec. 31, 2020USD ($) | Dec. 31, 2019USD ($) |
Schedule of Equity Method Investments [Line Items] | ||||
Payments to acquire equity method investments | $ 0 | $ 490,000 | $ 680,000 | |
Brim Acquisitions LLC | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Initial capital of acquisition | $ 2,000,000 | |||
Number of helicopters owned | helicopter | 4 | |||
Number of helicopters leased | helicopter | 5 | |||
Carrying value of equity method investment | 3,400,000 | 3,700,000 | ||
Other income (loss) | (300,000) | 600,000 | 1,000,000 | |
Payments to acquire equity method investments | $ 0 | $ 500,000 | $ 700,000 | |
Cobra Aviation Services LLC | Brim Acquisitions LLC | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Economic interest | 49.00% | |||
Cobra Aviation Services LLC | Brim Equipment Assets | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Cash paid to acquire a business | $ 2,000,000 | |||
Wexford Partners Investment Co. LLC | Brim Acquisitions LLC | ||||
Schedule of Equity Method Investments [Line Items] | ||||
Economic interest | 51.00% |
Accrued Expenses and Other Cu_3
Accrued Expenses and Other Current Liabilities and Other Long-Term Liabilities - Summary of Accrued Expenses and Other Current Liabilities and Other Long-Term Liabilities (Details) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Accrued Expenses and Other Current Liabilities | ||
Accrued legal settlement | $ 18,966 | $ 0 |
State and local taxes payable | 13,772 | 13,838 |
Financed insurance premiums | 9,852 | 10,394 |
Deferred revenue | 3,250 | 8,281 |
Accrued compensation and benefits | 5,133 | 3,710 |
Insurance reserves | 1,413 | 1,941 |
Payroll tax liability | 2,810 | 1,816 |
Accrued expenses and other current liabilities | 1,834 | 1,499 |
Failed sale leaseback liability | 3,340 | 1,290 |
Other | 2,146 | 1,639 |
Total accrued expenses and other current liabilities | 62,516 | 44,408 |
Other Long-Term Liabilities | ||
Financing leases | 4,375 | 4,618 |
Failed sale leaseback liability | 7,318 | 3,348 |
Payroll tax liability | 0 | 1,977 |
Other | 0 | 492 |
Total other long-term liabilities | $ 11,693 | $ 10,435 |
Accrued Expenses and Other Cu_4
Accrued Expenses and Other Current Liabilities and Other Long-Term Liabilities - Footnote (Details) - USD ($) $ in Millions | Jun. 01, 2021 | Dec. 30, 2020 | Dec. 31, 2021 | Dec. 31, 2020 |
Schedule of Other Operating Cost and Expense, by Component [Line Items] | ||||
Term of contract | 42 months | 36 months | ||
First National Capital, LLC | ||||
Schedule of Other Operating Cost and Expense, by Component [Line Items] | ||||
Proceeds from sale of assets | $ 9.5 | $ 5 | ||
Monthly rental payment amount | $ 0.2 | $ 0.1 | ||
Minimum | ||||
Schedule of Other Operating Cost and Expense, by Component [Line Items] | ||||
Financed insurance premium interest rate, percent | 1.95% | 3.45% | ||
Maximum | ||||
Schedule of Other Operating Cost and Expense, by Component [Line Items] | ||||
Financed insurance premium interest rate, percent | 2.45% | 3.75% |
Debt - Schedule of Debt (Detail
Debt - Schedule of Debt (Details) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Debt Disclosure [Abstract] | ||
Revolving credit facility | $ 83,370 | $ 78,000 |
Aviation note | 3,371 | 4,551 |
Unamortized debt issuance costs | (33) | (48) |
Total debt | 86,708 | 82,503 |
Current portion of long-term debt | 1,468 | 1,165 |
Long-term debt, net of current portion | $ 85,240 | $ 81,338 |
Debt - Narrative (Details)
Debt - Narrative (Details) $ in Thousands | Feb. 01, 2024USD ($) | Jul. 01, 2022 | Feb. 22, 2022USD ($) | Nov. 03, 2021USD ($) | Nov. 06, 2020USD ($) | Jun. 30, 2022 | Dec. 31, 2021USD ($) | May 31, 2022USD ($) | Apr. 01, 2022USD ($) | Mar. 31, 2022USD ($) | Mar. 02, 2022USD ($) | Feb. 28, 2022USD ($) | Nov. 02, 2021USD ($) | Dec. 31, 2020USD ($) |
Line of Credit Facility [Line Items] | ||||||||||||||
Percentage of minimum prepayments made with non-recurring proceeds to reduce revolving advance | 50.00% | |||||||||||||
Outstanding borrowing under the credit facility | $ 83,370 | $ 78,000 | ||||||||||||
Aviation note | 3,371 | 4,551 | ||||||||||||
Subsequent Event | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Basis spread on variable rate, percent | 2.00% | |||||||||||||
Percentage of minimum prepayments made with non-recurring proceeds to reduce revolving advance | 50.00% | |||||||||||||
Outstanding borrowing under the credit facility | $ 8,500 | |||||||||||||
Leopard and Cobra Aviation | Aviation Note | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Term of note | 39 months | |||||||||||||
Aviation note | $ 4,600 | |||||||||||||
Proceeds from notes payable | 4,500 | |||||||||||||
Debt instrument, periodic payment | $ 100 | |||||||||||||
Certificates of deposit | $ 1,800 | |||||||||||||
Leopard and Cobra Aviation | Aviation Note | Scenario, Forecast | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Debt instrument, periodic payment | $ 200 | |||||||||||||
Minimum | Leopard and Cobra Aviation | Aviation Note | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Interest coverage ratio | 1.25 | |||||||||||||
Prime Rate | Leopard and Cobra Aviation | Aviation Note | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Basis spread on variable rate, percent | 1.00% | |||||||||||||
Revolving Credit Facility | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Maximum borrowing capacity | $ 120,000 | $ 130,000 | ||||||||||||
Debt instrument, debt covenant, minimum adjusted EBITDA required | 6,000 | |||||||||||||
Debt instrument, debt covenant, minimum excess availability covenant | $ 10,000 | |||||||||||||
Remaining borrowing capacity | $ 16,500 | 38,700 | ||||||||||||
Revolving Credit Facility | Subsequent Event | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Debt instrument, debt covenant, minimum adjusted EBITDA required | $ 4,700 | |||||||||||||
Debt instrument, debt covenant, minimum excess availability covenant | $ 10,000 | $ 7,500 | 7,500 | |||||||||||
Revolving Credit Facility | Minimum | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Interest coverage ratio | 1.1 | |||||||||||||
Revolving Credit Facility | Minimum | Subsequent Event | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Interest coverage ratio | 1.1 | 0.85 | ||||||||||||
Letter of Credit | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Remaining borrowing capacity | $ 9,000 | $ 13,000 | ||||||||||||
Letter of Credit | Subsequent Event | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Debt instrument, debt covenant, minimum excess availability covenant for restricted payments | $ 20,000 | |||||||||||||
Line of Credit | Revolving Credit Facility | Subsequent Event | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Outstanding borrowing under the credit facility | 83,700 | |||||||||||||
Remaining borrowing capacity | $ 10,000 | $ 10,600 | ||||||||||||
Line of Credit | Revolving Credit Facility | Base Rate | Maximum | ||||||||||||||
Line of Credit Facility [Line Items] | ||||||||||||||
Basis spread on variable rate, percent | 3.50% |
Variable Interest Entities (Det
Variable Interest Entities (Details) - helicopter | Apr. 06, 2018 | Dec. 31, 2021 |
ARS | ||
Variable Interest Entity [Line Items] | ||
Ownership percentage | 100.00% | |
Brim Acquisitions LLC | ||
Variable Interest Entity [Line Items] | ||
Ownership percentage | 49.00% | |
Cobra Aviation Services LLC | ||
Variable Interest Entity [Line Items] | ||
Number of helicopters owned | 2 | |
Cobra Aviation Services LLC | Dire Wolf Energy Services LLC | ||
Variable Interest Entity [Line Items] | ||
Interest transferred | 100.00% | |
Leopard Aviation LLC | ||
Variable Interest Entity [Line Items] | ||
Number of helicopters owned | 1 | |
Leopard Aviation LLC | Predator Aviation LLC | ||
Variable Interest Entity [Line Items] | ||
Interest transferred | 100.00% |
Selling, General and Administ_3
Selling, General and Administrative Expense (Details) - USD ($) $ in Thousands | 3 Months Ended | 12 Months Ended | ||
Mar. 31, 2021 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Non-cash expenses: | ||||
Bad debt provision | $ 41,662 | $ 21,958 | $ 1,434 | |
Stock based compensation | 1,191 | 1,952 | 4,177 | |
Total SG&A expense | 78,246 | 67,185 | 51,552 | |
Gulfport | ||||
Non-cash expenses: | ||||
Bad debt provision | $ 3,800 | |||
Selling, General and Administrative Expenses | ||||
Cash expenses: | ||||
Compensation and benefits | 15,064 | 14,876 | 19,364 | |
Professional services | 11,400 | 19,905 | 17,128 | |
Other | 9,052 | 8,828 | 10,300 | |
Total cash SG&A expense | 35,516 | 43,609 | 46,792 | |
Non-cash expenses: | ||||
Bad debt provision | 41,662 | 21,958 | 1,434 | |
Stock based compensation | 1,068 | 1,618 | 3,326 | |
Total non-cash SG&A expense | 42,730 | 23,576 | 4,760 | |
Total SG&A expense | 78,246 | 67,185 | $ 51,552 | |
Selling, General and Administrative Expenses | Gulfport | ||||
Non-cash expenses: | ||||
Bad debt provision | $ 41,200 | $ 19,400 |
Income Taxes - Components of In
Income Taxes - Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Income Tax Disclosure [Abstract] | |||
U.S. current income tax expense (benefit) | $ 290 | $ (6,931) | $ 386 |
U.S. deferred income tax benefit | (23,740) | (12,330) | (21,761) |
Foreign current income tax expense | 8,852 | 6,948 | 30,172 |
Foreign deferred income tax (benefit) expense | (8,265) | 144 | (20,878) |
Total | $ (22,863) | $ (12,169) | $ (12,081) |
Income Taxes - Income Tax Recon
Income Taxes - Income Tax Reconciliation (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Income Tax Disclosure [Abstract] | |||
Loss before income taxes | $ (124,293) | $ (119,776) | $ (91,125) |
Statutory income tax rate | 21.00% | 21.00% | 21.00% |
Expected income tax (benefit) expense | $ (26,102) | $ (25,153) | $ (19,136) |
Change in tax rate | 0 | (161) | 0 |
Change in uncertain tax positions | 1,043 | 0 | 0 |
Foreign income tax rate differential | (282) | 2,556 | 9,387 |
Foreign (loss) earnings not in reported income | (336) | 3,252 | 12,581 |
Foreign tax credits | (7,749) | (7,133) | (26,141) |
Withholding taxes | (49) | 1,019 | 3,635 |
Goodwill impairment | 52 | 11,544 | 6,506 |
Other permanent differences | 426 | 1,290 | 1,873 |
State tax expenses | (2,449) | (1,664) | 2,364 |
CARES act | 0 | (2,378) | 0 |
Return to provision | 390 | 894 | (15,156) |
Change in valuation allowance | 12,193 | 3,765 | 12,006 |
Total | $ (22,863) | $ (12,169) | $ (12,081) |
Income Taxes - Narrative (Detai
Income Taxes - Narrative (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Income Tax Examination [Line Items] | |||
Effective income tax rate | 18.40% | 10.20% | 13.30% |
Additions for tax positions of prior years | $ 1,043 | ||
Income tax benefit | 22,863 | $ 12,169 | $ 12,081 |
Changes in valuation allowance | 12,200 | 3,800 | |
Foreign Tax Authority | |||
Income Tax Examination [Line Items] | |||
Tax credit carryforwards | $ 83,800 | ||
Coronavirus Aid, Relief, and Economic Security (CARES) Act | |||
Income Tax Examination [Line Items] | |||
Income tax benefit | 2,400 | ||
Current income tax benefit | 7,000 | ||
Deferred income tax expense | $ 4,600 |
Income Taxes - Deferred Income
Income Taxes - Deferred Income Tax Assets and Liabilities (Details) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Deferred tax assets: | ||
Allowance for doubtful accounts | $ 1,241 | $ 1,541 |
Lease asset | 4,432 | 6,060 |
Intangible assets | 1,070 | 0 |
Accrued liabilities | 12,833 | 740 |
Net operating loss carryover | 13,447 | 613 |
Foreign tax credits | 83,780 | 80,615 |
Other | 1,652 | 1,919 |
Valuation allowance | (71,612) | (67,888) |
Deferred tax assets | 46,843 | 23,600 |
Deferred tax liabilities: | ||
Property and equipment | (28,126) | (39,057) |
Intangible assets | 0 | (450) |
Lease liability | (4,392) | (6,030) |
Other | (7,096) | (2,804) |
Deferred tax liabilities | (39,614) | (48,341) |
Reflected in accompanying balance sheet as: | ||
Deferred income tax asset | 8,094 | 0 |
Deferred income tax liability | (865) | (24,741) |
Net deferred tax asset (liability) | $ (24,741) | |
Net deferred tax asset (liability) | $ 7,229 |
Income Taxes - Uncertain Tax Po
Income Taxes - Uncertain Tax Positions (Details) $ in Thousands | 12 Months Ended |
Dec. 31, 2021USD ($) | |
Income Tax Disclosure [Abstract] | |
Beginning balance | $ 0 |
Additions for tax positions of prior years | 1,043 |
Ending balance | $ 1,043 |
Leases - Schedule of Lease Expe
Leases - Schedule of Lease Expense (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2021 | Dec. 31, 2020 | |
Leases [Abstract] | ||
Operating lease expense | $ 9,156 | $ 13,735 |
Short-term lease expense | 335 | 812 |
Amortization of right-of-use assets | 1,582 | 1,311 |
Interest on lease liabilities | 202 | 203 |
Total lease expense | $ 11,275 | $ 16,061 |
Leases - Supplemental Balance S
Leases - Supplemental Balance Sheet Information (Details) - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Operating leases: | ||
Operating lease right-of-use assets | $ 12,168 | $ 20,179 |
Current operating lease liability | 5,942 | 8,618 |
Long-term operating lease liability | 5,918 | 11,377 |
Finance leases: | ||
Property and equipment, net | 6,065 | 6,065 |
Accrued expenses and other current liabilities | 1,834 | 1,499 |
Other liabilities | $ 4,375 | $ 4,618 |
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration] | Property, plant and equipment, net | Property, plant and equipment, net |
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration] | Accrued expenses and other current liabilities | Accrued expenses and other current liabilities |
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration] | Other long-term liabilities | Other long-term liabilities |
Leases - Other Supplemental Inf
Leases - Other Supplemental Information Related to Leases (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Cash paid for amounts included in the measurement of lease liabilities: | |||
Operating cash flows from operating leases | $ 9,284 | $ 13,643 | |
Operating cash flows from finance leases | 202 | 203 | |
Financing cash flows from finance leases | 1,677 | 1,318 | |
Right-of-use assets obtained in exchange for lease obligations: | |||
Operating leases | 594 | (10,260) | |
Finance leases | $ 1,750 | $ 2,431 | $ 3,721 |
Weighted-average remaining lease term: | |||
Operating leases | 3 years 1 month 6 days | 3 years 2 months 12 days | |
Finance leases | 3 years 3 months 18 days | 4 years 2 months 12 days | |
Weighted-average discount rate: | |||
Operating leases | 3.30% | 3.50% | |
Finance leases | 3.30% | 3.50% |
Leases - Schedule of Lease Liab
Leases - Schedule of Lease Liability Maturity (Details) $ in Thousands | Dec. 31, 2021USD ($) |
Operating Leases | |
2022 | $ 6,214 |
2023 | 3,600 |
2024 | 1,641 |
2025 | 517 |
2026 | 147 |
Thereafter | 407 |
Total lease payments | 12,526 |
Less: Present value discount | 666 |
Present value of lease payments | 11,860 |
Finance Leases | |
2022 | 2,005 |
2023 | 2,261 |
2024 | 965 |
2025 | 524 |
2026 | 795 |
Thereafter | 0 |
Total lease payments | 6,550 |
Less: Present value discount | 341 |
Present value of lease payments | $ 6,209 |
Leases - Narrative (Details)
Leases - Narrative (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Service | |||
Lessee, Lease, Description [Line Items] | |||
Lease Income | $ 2.4 | $ 1.4 | $ 2.3 |
Dividends and Earnings (Loss)_3
Dividends and Earnings (Loss) Per Share - Dividends (Details) - USD ($) $ / shares in Units, $ in Thousands | May 17, 2019 | Feb. 14, 2019 | Dec. 31, 2019 |
Equity [Abstract] | |||
Cash dividends (in dollars per share) | $ 0.125 | $ 0.125 | $ 0.25 |
Cash dividends | $ 5,610 | $ 5,609 | $ 11,219 |
Dividends and Earnings (Loss)_4
Dividends and Earnings (Loss) Per Share - Basic and Diluted Earnings (Loss) Per Share (Details) - USD ($) $ / shares in Units, $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Basic loss per share: | |||
Net loss | $ (101,430) | $ (107,607) | $ (79,044) |
Weighted average number of shares outstanding (in shares) | 46,428,000 | 45,644,000 | 45,011,000 |
Basic loss per share (in dollars per share) | $ (2.18) | $ (2.36) | $ (1.76) |
Diluted loss per share: | |||
Net loss | $ (101,430) | $ (107,607) | $ (79,044) |
Weighted average common shares, including dilutive effect (in shares) | 46,428,000 | 45,644,000 | 45,011,000 |
Diluted loss per share (in dollars per share) | $ (2.18) | $ (2.36) | $ (1.76) |
Restricted Stock | |||
Diluted loss per share: | |||
Incremental common shares attributable to dilutive effect of share-based payment arrangements (in shares) | 0 | 0 | 0 |
Equity Based Compensation - Nar
Equity Based Compensation - Narrative (Details) $ in Millions | Dec. 31, 2021USD ($) |
Specified Member Awards | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Fair value of the award as of the modification dates or grant date | $ 5.6 |
Non-Employees Member | Payout Provision | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Fair value of the award as of the modification dates or grant date | $ 18.9 |
Stock-Based Compensation - Narr
Stock-Based Compensation - Narrative (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Share-based compensation, number of shares authorized (in shares) | 4,500,000 | ||
Restricted Stock | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Unrecognized compensation cost | $ 0.8 | ||
Weighted-average period of unrecognized compensation cost | 1 year | ||
Compensation expense | $ 1.2 | $ 2 | $ 4.2 |
Stock-Based Compensation - Summ
Stock-Based Compensation - Summary of Unvested Shares of Restricted Stock Units (Details) - Restricted Stock - $ / shares | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Number of Unvested Restricted Stock Units | |||
Unvested restricted stock units, beginning of the period (in shares) | 1,914,782 | 221,241 | 434,119 |
Granted (in shares) | 128,205 | 2,401,446 | 101,181 |
Vested (in shares) | (914,782) | (660,738) | (231,896) |
Forfeited (in shares) | 0 | (47,167) | (82,163) |
Unvested restricted stock units, ending of the period (in shares) | 1,128,205 | 1,914,782 | 221,241 |
Weighted Average Grant-Date Fair Value | |||
Unvested restricted stock units, beginning of the period (in dollars per share) | $ 1.21 | $ 22.43 | $ 22.78 |
Granted (in dollars per share) | 3.90 | 0.98 | 6.83 |
Vested (in dollars per share) | 1.52 | 5.32 | 22.45 |
Forfeited (in dollars per share) | 0 | 3.28 | 18.55 |
Unvested restricted stock units, ending of the period (in dollars per share) | $ 1.27 | $ 1.21 | $ 22.43 |
Related Party Transactions - Re
Related Party Transactions - Revenues and Accounts Receivable (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Related Party Transaction [Line Items] | |||
ACCOUNTS RECEIVABLE | $ 88 | $ 28,461 | |
Related parties | |||
Related Party Transaction [Line Items] | |||
REVENUES | 17,939 | 50,591 | $ 130,313 |
ACCOUNTS RECEIVABLE | 88 | 26,617 | |
OTHER | 515 | 1,890 | 0 |
ACCOUNTS RECEIVABLE | 0 | 1,844 | |
ACCOUNTS RECEIVABLE | 88 | 28,461 | |
Stingray Pressure Pumping and Gulfport | Related parties | |||
Related Party Transaction [Line Items] | |||
REVENUES | 14,812 | 42,460 | 90,357 |
ACCOUNTS RECEIVABLE | 0 | 25,429 | |
OTHER | 514 | 1,887 | 0 |
ACCOUNTS RECEIVABLE | 0 | 1,841 | |
Muskie and Gulfport | Related parties | |||
Related Party Transaction [Line Items] | |||
REVENUES | 2,145 | 7,500 | 27,689 |
ACCOUNTS RECEIVABLE | 0 | 1,127 | |
OTHER | 1 | 3 | 0 |
ACCOUNTS RECEIVABLE | 0 | 3 | |
SR Energy and Gulfport | Related parties | |||
Related Party Transaction [Line Items] | |||
REVENUES | 0 | 113 | 8,772 |
ACCOUNTS RECEIVABLE | 0 | 8 | |
Aquahawk and Gulfport | Related parties | |||
Related Party Transaction [Line Items] | |||
REVENUES | 0 | 0 | 828 |
ACCOUNTS RECEIVABLE | 0 | 0 | |
Cobra Aviation/ARS/Leopard and Brim Equipment | Related parties | |||
Related Party Transaction [Line Items] | |||
REVENUES | 371 | 446 | 2,093 |
ACCOUNTS RECEIVABLE | 85 | 44 | |
Panther and El Toro | Related parties | |||
Related Party Transaction [Line Items] | |||
REVENUES | 599 | 38 | 573 |
ACCOUNTS RECEIVABLE | 0 | 0 | |
Other Relationships | Related parties | |||
Related Party Transaction [Line Items] | |||
REVENUES | 12 | 34 | $ 1 |
ACCOUNTS RECEIVABLE | $ 3 | $ 9 |
Related Party Transactions - Co
Related Party Transactions - Cost of Revenues of Accounts Payable (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Related Party Transaction [Line Items] | |||
SELLING, GENERAL AND ADMINISTRATIVE COSTS | $ 385 | $ 758 | $ 1,847 |
Related parties | |||
Related Party Transaction [Line Items] | |||
COST OF REVENUE | 531 | 418 | 4,770 |
ACCOUNTS PAYABLE | 5 | 3 | |
SELLING, GENERAL AND ADMINISTRATIVE COSTS | 387 | 758 | 1,847 |
CAPITAL EXPENDITURES | 0 | 0 | 420 |
Cobra Aviation/ARS/Leopard and Brim Equipment | Related parties | |||
Related Party Transaction [Line Items] | |||
COST OF REVENUE | 73 | 72 | 4,720 |
The Company and Caliber | Related parties | |||
Related Party Transaction [Line Items] | |||
COST OF REVENUE | 351 | 248 | 0 |
The Company and Wexford | Related parties | |||
Related Party Transaction [Line Items] | |||
SELLING, GENERAL AND ADMINISTRATIVE COSTS | 5 | 3 | 650 |
The Company and Caliber | Related parties | |||
Related Party Transaction [Line Items] | |||
SELLING, GENERAL AND ADMINISTRATIVE COSTS | 374 | 774 | 785 |
Cobra Aviation/ARS/Leopard and Brim Equipment | Related parties | |||
Related Party Transaction [Line Items] | |||
SELLING, GENERAL AND ADMINISTRATIVE COSTS | 0 | 0 | 233 |
Other Relationships | Related parties | |||
Related Party Transaction [Line Items] | |||
COST OF REVENUE | 107 | 98 | 50 |
SELLING, GENERAL AND ADMINISTRATIVE COSTS | 8 | (19) | 179 |
Leopard and Brim Equipment | Related parties | |||
Related Party Transaction [Line Items] | |||
CAPITAL EXPENDITURES | 0 | 0 | $ 420 |
ACCOUNTS PAYABLE | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | 5 | 1 | |
ACCOUNTS PAYABLE | Cobra Aviation/ARS/Leopard and Brim Equipment | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | 5 | 1 | |
ACCOUNTS PAYABLE | The Company and Caliber | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | 0 | 0 | |
ACCOUNTS PAYABLE | Other Relationships | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | 0 | 0 | |
SELLING, GENERAL AND ADMINISTRATIVE COSTS | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | 0 | 2 | |
SELLING, GENERAL AND ADMINISTRATIVE COSTS | The Company and Wexford | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | 0 | 2 | |
SELLING, GENERAL AND ADMINISTRATIVE COSTS | The Company and Caliber | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | 0 | 0 | |
SELLING, GENERAL AND ADMINISTRATIVE COSTS | Cobra Aviation/ARS/Leopard and Brim Equipment | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | 0 | ||
SELLING, GENERAL AND ADMINISTRATIVE COSTS | Other Relationships | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | 0 | 0 | |
CAPITAL EXPENDITURES | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | 0 | 0 | |
CAPITAL EXPENDITURES | Leopard and Brim Equipment | Related parties | |||
Related Party Transaction [Line Items] | |||
ACCOUNTS PAYABLE | $ 0 | $ 0 |
Related Party Transactions - Na
Related Party Transactions - Narrative (Details) - USD ($) | 12 Months Ended | |||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | Dec. 21, 2018 | |
Related Party Transaction [Line Items] | ||||
Contributions to equity investee | $ 0 | $ 490,000 | $ 680,000 | |
Wexford | ||||
Related Party Transaction [Line Items] | ||||
Ownership percentage | 48.00% | |||
Brim Acquisitions LLC | ||||
Related Party Transaction [Line Items] | ||||
Initial capital of acquisition | $ 2,000,000 | |||
Contributions to equity investee | $ 0 | $ 500,000 | $ 700,000 | |
Cobra Aviation Services LLC | Brim Acquisitions LLC | ||||
Related Party Transaction [Line Items] | ||||
Equity method investment, ownership percentage | 49.00% | |||
Wexford Partners Investment Co. LLC | Brim Acquisitions LLC | ||||
Related Party Transaction [Line Items] | ||||
Equity method investment, ownership percentage | 51.00% |
Commitments and Contingencies -
Commitments and Contingencies - Narrative (Details) | Dec. 01, 2022USD ($) | Aug. 01, 2022USD ($) | Oct. 28, 2021USD ($) | Sep. 21, 2021USD ($) | Aug. 02, 2021USD ($) | May 13, 2021USD ($) | Mar. 25, 2020USD ($) | Oct. 31, 2019lawsuit | Sep. 30, 2019lawsuit | Sep. 30, 2021USD ($) | Mar. 31, 2021USD ($) | Aug. 31, 2019lawsuit | Dec. 31, 2021USD ($) | Dec. 31, 2020USD ($) | Dec. 31, 2019USD ($) | May 26, 2021USD ($) | Nov. 13, 2020USD ($) | Jan. 21, 2020USD ($) | Sep. 13, 2019lawsuit |
Guarantor Obligations [Line Items] | |||||||||||||||||||
Workers compensation, deductible | $ 300,000 | $ 100,000 | |||||||||||||||||
Workers compensation insurance aggregate stop loss | 5,400,000 | 5,400,000 | |||||||||||||||||
Accrued workers’ compensation and auto claims | 1,400,000 | 1,900,000 | |||||||||||||||||
Directors and officers liability deductible per occurrence | 1,000,000 | 1,000,000 | |||||||||||||||||
Directors and officers liability aggregate deductible limit | 10,000,000 | 10,000,000 | |||||||||||||||||
Self insurance, aggregate stop loss per claim basis | 200,000 | ||||||||||||||||||
Self insurance, aggregate stop loss per calendar year | 5,800,000 | ||||||||||||||||||
Self insurance, claims accrued | 1,600,000 | 1,300,000 | |||||||||||||||||
Warranty accrual | 0 | 0 | |||||||||||||||||
Product warranty expense | 0 | 0 | $ 0 | ||||||||||||||||
Outstanding bid bonds | |||||||||||||||||||
Recovery amount in undisputed claims | $ 61,700,000 | ||||||||||||||||||
Revenues | 228,962,000 | 313,076,000 | 625,012,000 | ||||||||||||||||
Bad debt expense | 41,662,000 | 21,958,000 | $ 1,434,000 | ||||||||||||||||
Receivables from related parties, net | 88,000 | 28,461,000 | |||||||||||||||||
Contracts amount | $ 100,000,000 | ||||||||||||||||||
Legal settlement, amount | $ 6,500,000 | 25,000,000 | |||||||||||||||||
Contracts receivable, claims and uncertain amounts, expected to be collected, term | 10 days | ||||||||||||||||||
Litigation settlement, expense | 5,400,000 | ||||||||||||||||||
Accrued legal settlement | 18,966,000 | 0 | |||||||||||||||||
Litigation settlement interest | 500,000 | ||||||||||||||||||
Accounts Payable and Accrued Liabilities | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Accrued legal settlement | 19,000,000 | ||||||||||||||||||
Capital Addition Purchase Commitments | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Purchase obligation | 1,400,000 | ||||||||||||||||||
Minimum | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Litigation settlement, interest-bearing, interest rate | 6.00% | ||||||||||||||||||
Maximum | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Litigation settlement, interest-bearing, interest rate | 12.00% | ||||||||||||||||||
Scenario, Forecast | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Legal settlement, amount | $ 9,250,000 | $ 9,250,000 | |||||||||||||||||
Outstanding Bid Bond | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Outstanding bid bonds | 600,000 | 1,000,000 | |||||||||||||||||
Puerto Rico Electric Power Authority (PREPA) | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Interest charged on accounts receivable | 110,800,000 | 74,300,000 | |||||||||||||||||
Accounts receivable, contract costs, amount expected to be authorized | $ 47,000,000 | ||||||||||||||||||
Gulfport | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Interest charged on accounts receivable | 1,400,000 | $ 3,300,000 | |||||||||||||||||
Due from related parties | 19,400,000 | 46,900,000 | |||||||||||||||||
Litigation liability | 1,800,000 | $ 1,800,000 | |||||||||||||||||
Unliquidated damages | $ 46,400,000 | ||||||||||||||||||
Revenues | (27,100,000) | ||||||||||||||||||
Bad debt expense | 3,800,000 | ||||||||||||||||||
Receivables from related parties, net | 100,000 | ||||||||||||||||||
Gulfport | Pre-Petition Receivables | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Receivables from related parties, net | 500,000 | ||||||||||||||||||
Gulfport | Pre-Petition Products And Services | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Receivables from related parties, net | 6,100,000 | ||||||||||||||||||
Mastec Renewables Puerto Rico, LLC | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Contracts amount | $ 500,000,000 | ||||||||||||||||||
Foreman Electric Services, Inc. | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Loss contingency, damages awarded, value | $ 250,000,000 | ||||||||||||||||||
Puerto Rico Electric Power Authority (PREPA) | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Accounts receivable, related parties | 227,000,000 | ||||||||||||||||||
Muskie and Gulfport | Gulfport | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Bad debt expense | $ 200,000 | ||||||||||||||||||
General unsecured claim | $ 3,100,000 | ||||||||||||||||||
Stingray Pressure Pumping | Gulfport | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Unliquidated damages | 37,900,000 | ||||||||||||||||||
Bad debt expense | 31,000,000 | $ 2,900,000 | |||||||||||||||||
Other expenses | $ 1,300,000 | ||||||||||||||||||
Performance And Payment Bond | Performance Guarantee | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Guarantee | 20,300,000 | $ 18,100,000 | |||||||||||||||||
Bid Bond | Performance Guarantee | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Estimated costs to complete projects secured by performance and payment bonds | $ 4,700,000 | ||||||||||||||||||
Western District Of Oklahoma, Federal Securities Lawsuits | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Loss contingency, damages awarded, value | $ 500,000 | ||||||||||||||||||
Number of new claims filed | lawsuit | 2 | 3 | |||||||||||||||||
Number of claims combined | lawsuit | 3 | ||||||||||||||||||
Cash paid for settlement | $ 1,500,000 | $ 11,000,000 | |||||||||||||||||
Number of claims dismissed | lawsuit | 2 | ||||||||||||||||||
September 2019 Derivative Lawsuits | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Number of new claims filed | lawsuit | 4 | ||||||||||||||||||
District of Delaware, Federal Securities Lawsuits | |||||||||||||||||||
Guarantor Obligations [Line Items] | |||||||||||||||||||
Number of new claims filed | lawsuit | 2 |
Commitments and Contingencies_2
Commitments and Contingencies - Schedule of Letters of Credit (Details) - Letter of Credit - USD ($) $ in Thousands | Dec. 31, 2021 | Dec. 31, 2020 |
Line of Credit Facility [Line Items] | ||
Total letters of credit | $ 9,039 | $ 13,039 |
Bonding program | ||
Line of Credit Facility [Line Items] | ||
Total letters of credit | 1,000 | 5,000 |
Environmental remediation | ||
Line of Credit Facility [Line Items] | ||
Total letters of credit | 3,694 | 3,694 |
Insurance programs | ||
Line of Credit Facility [Line Items] | ||
Total letters of credit | 3,890 | 3,890 |
Rail car commitments | ||
Line of Credit Facility [Line Items] | ||
Total letters of credit | $ 455 | $ 455 |
Commitments and Contingencies_3
Commitments and Contingencies - Defined Contribution Plan (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | |
Commitments and Contingencies Disclosure [Abstract] | |||
Defined contribution plan, maximum annual contributions per employee, percent | 92.00% | ||
Defined benefit plan, employer matching contribution, percent of match (up to) | 3.00% | ||
Defined benefit plan, contributions by employer | $ 1.8 | $ 2 | $ 3.3 |
Reporting Segments and Geogra_3
Reporting Segments and Geographic Areas (Details) $ in Thousands | 3 Months Ended | 12 Months Ended | ||||
Mar. 31, 2020USD ($) | Dec. 31, 2019USD ($) | Sep. 30, 2019USD ($) | Dec. 31, 2021USD ($)segment | Dec. 31, 2020USD ($) | Dec. 31, 2019USD ($) | |
Segment Reporting Information [Line Items] | ||||||
Number of reportable segments | segment | 4 | |||||
Total Revenue | $ 228,962 | $ 313,076 | $ 625,012 | |||
Cost of revenue, exclusive of depreciation, depletion, amortization and accretion | 198,326 | 232,021 | 543,788 | |||
Intersegment cost of revenues | 0 | 0 | 0 | |||
Total cost of revenue | 198,326 | 232,021 | 543,788 | |||
Selling, general and administrative | 78,246 | 67,185 | 51,552 | |||
Depreciation, depletion, amortization and accretion | 78,475 | 95,317 | 117,033 | |||
Impairment of goodwill | $ 55,000 | $ 30,500 | $ 3,200 | 891 | 54,973 | 33,664 |
Impairment of other long-lived assets | $ 12,900 | 1,212 | 12,897 | 7,358 | ||
Operating loss | (128,188) | (149,317) | (128,383) | |||
Interest expense | 6,406 | 5,397 | 4,958 | |||
Other (income) expense, net | (10,301) | (34,938) | (42,216) | |||
Income (loss) before income taxes | (124,293) | (119,776) | (91,125) | |||
Total expenditures for property, plant and equipment | 5,843 | 6,837 | 35,761 | |||
Intangible assets, net | 5,788 | 2,561 | 4,774 | 5,788 | ||
Total assets | 952,385 | 720,892 | 824,562 | 952,385 | ||
Long-lived assets | 545,405 | 272,015 | 359,814 | 545,405 | ||
Intersegment revenues | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 0 | 0 | 0 | |||
Eliminations | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | (6,466) | (3,974) | (49,688) | |||
Cost of revenue, exclusive of depreciation, depletion, amortization and accretion | 0 | 0 | 0 | |||
Intersegment cost of revenues | (6,466) | (3,974) | (49,748) | |||
Total cost of revenue | (6,466) | (3,974) | (49,748) | |||
Selling, general and administrative | 0 | 0 | 0 | |||
Depreciation, depletion, amortization and accretion | 0 | 0 | 0 | |||
Impairment of goodwill | 0 | 0 | 0 | |||
Impairment of other long-lived assets | 0 | 0 | 0 | |||
Operating loss | 0 | 0 | 60 | |||
Interest expense | 0 | 0 | 0 | |||
Other (income) expense, net | 0 | 0 | 0 | |||
Income (loss) before income taxes | 0 | 0 | 60 | |||
Total expenditures for property, plant and equipment | 0 | 0 | 0 | |||
Intangible assets, net | 0 | 0 | 0 | 0 | ||
Total assets | (52,072) | (75,948) | (57,582) | (52,072) | ||
United States | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 217,958 | 302,205 | 516,276 | |||
Long-lived assets | 526,584 | 258,666 | 342,838 | 526,584 | ||
Puerto Rico | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 0 | 53 | 96,630 | |||
Canada | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 10,685 | 10,723 | 11,946 | |||
Long-lived assets | 18,821 | 13,349 | 16,976 | 18,821 | ||
Other | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 319 | 95 | 160 | |||
Infrastructure | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 93,403 | 157,751 | 210,712 | |||
Impairment of goodwill | 891 | 0 | ||||
Infrastructure | Intersegment revenues | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 0 | 0 | 2,573 | |||
Infrastructure | Operating Segments | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 93,403 | 157,751 | 213,285 | |||
Cost of revenue, exclusive of depreciation, depletion, amortization and accretion | 90,363 | 124,232 | 160,731 | |||
Intersegment cost of revenues | 196 | 323 | 12,820 | |||
Total cost of revenue | 90,559 | 124,555 | 173,551 | |||
Selling, general and administrative | 18,267 | 27,261 | 23,616 | |||
Depreciation, depletion, amortization and accretion | 21,880 | 29,373 | 30,349 | |||
Impairment of goodwill | 891 | 0 | 0 | |||
Impairment of other long-lived assets | 665 | 0 | 0 | |||
Operating loss | (38,859) | (23,438) | (14,231) | |||
Interest expense | 3,925 | 2,794 | 1,674 | |||
Other (income) expense, net | (6,785) | (32,437) | (41,949) | |||
Income (loss) before income taxes | (35,999) | 6,205 | 26,044 | |||
Total expenditures for property, plant and equipment | 627 | 258 | 3,456 | |||
Intangible assets, net | 1,296 | 165 | 1,063 | 1,296 | ||
Total assets | 420,755 | 427,626 | 437,296 | 420,755 | ||
Well Completion | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 84,190 | 87,201 | 241,951 | |||
Impairment of goodwill | 0 | 53,406 | ||||
Well Completion | Intersegment revenues | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 144 | 1,124 | 1,851 | |||
Well Completion | Operating Segments | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 84,334 | 88,325 | 243,802 | |||
Cost of revenue, exclusive of depreciation, depletion, amortization and accretion | 58,782 | 45,647 | 174,816 | |||
Intersegment cost of revenues | 5,770 | 1,836 | 31,727 | |||
Total cost of revenue | 64,552 | 47,483 | 206,543 | |||
Selling, general and administrative | 49,275 | 23,039 | 10,889 | |||
Depreciation, depletion, amortization and accretion | 26,377 | 30,411 | 40,159 | |||
Impairment of goodwill | 0 | 53,406 | 23,423 | |||
Impairment of other long-lived assets | 0 | 4,203 | 0 | |||
Operating loss | (55,870) | (70,217) | (37,212) | |||
Interest expense | 1,107 | 1,130 | 1,228 | |||
Other (income) expense, net | 1,073 | (2,274) | 580 | |||
Income (loss) before income taxes | (58,050) | (69,073) | (39,020) | |||
Total expenditures for property, plant and equipment | 4,327 | 4,358 | 14,703 | |||
Intangible assets, net | 3,371 | 1,995 | 2,683 | 3,371 | ||
Total assets | 172,608 | 56,036 | 99,247 | 172,608 | ||
Sand | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 30,880 | 34,265 | 67,267 | |||
Sand | Intersegment revenues | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 3,980 | 95 | 29,796 | |||
Sand | Operating Segments | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 34,860 | 34,360 | 97,063 | |||
Cost of revenue, exclusive of depreciation, depletion, amortization and accretion | 27,232 | 25,955 | 87,637 | |||
Intersegment cost of revenues | 0 | 0 | 15 | |||
Total cost of revenue | 27,232 | 25,955 | 87,652 | |||
Selling, general and administrative | 5,351 | 7,807 | 5,006 | |||
Depreciation, depletion, amortization and accretion | 9,005 | 9,771 | 14,050 | |||
Impairment of goodwill | 0 | 0 | 2,684 | |||
Impairment of other long-lived assets | 0 | 0 | 0 | |||
Operating loss | (6,728) | (9,173) | (12,329) | |||
Interest expense | 474 | 312 | 193 | |||
Other (income) expense, net | (874) | 1,839 | 67 | |||
Income (loss) before income taxes | (6,328) | (11,324) | (12,589) | |||
Total expenditures for property, plant and equipment | 484 | 1,073 | 2,877 | |||
Intangible assets, net | 0 | 0 | 0 | 0 | ||
Total assets | 189,415 | 156,519 | 172,927 | 189,415 | ||
Drilling | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 4,197 | 7,746 | 31,728 | |||
Drilling | Intersegment revenues | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 124 | 39 | 236 | |||
Drilling | Operating Segments | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 4,321 | 7,785 | 31,964 | |||
Cost of revenue, exclusive of depreciation, depletion, amortization and accretion | 6,102 | 10,757 | 35,925 | |||
Intersegment cost of revenues | 0 | 152 | 1,028 | |||
Total cost of revenue | 6,102 | 10,909 | 36,953 | |||
Selling, general and administrative | 1,414 | 3,149 | 4,177 | |||
Depreciation, depletion, amortization and accretion | 7,996 | 10,039 | 13,143 | |||
Impairment of goodwill | 0 | 0 | 0 | |||
Impairment of other long-lived assets | 0 | 326 | 2,955 | |||
Operating loss | (11,191) | (16,638) | (25,264) | |||
Interest expense | 293 | 454 | 862 | |||
Other (income) expense, net | (177) | (227) | (9) | |||
Income (loss) before income taxes | (11,307) | (16,865) | (26,117) | |||
Total expenditures for property, plant and equipment | 44 | 432 | 3,156 | |||
Intangible assets, net | 0 | 0 | 0 | 0 | ||
Total assets | 55,273 | 27,457 | 36,252 | 55,273 | ||
All Other | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 16,292 | 26,113 | 73,354 | |||
Impairment of goodwill | 0 | 1,567 | ||||
All Other | Intersegment revenues | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 2,218 | 2,716 | 15,232 | |||
All Other | Operating Segments | ||||||
Segment Reporting Information [Line Items] | ||||||
Total Revenue | 18,510 | 28,829 | 88,586 | |||
Cost of revenue, exclusive of depreciation, depletion, amortization and accretion | 15,847 | 25,430 | 84,679 | |||
Intersegment cost of revenues | 500 | 1,663 | 4,158 | |||
Total cost of revenue | 16,347 | 27,093 | 88,837 | |||
Selling, general and administrative | 3,939 | 5,929 | 7,864 | |||
Depreciation, depletion, amortization and accretion | 13,217 | 15,723 | 19,332 | |||
Impairment of goodwill | 0 | 1,567 | 7,557 | |||
Impairment of other long-lived assets | 547 | 8,368 | 4,403 | |||
Operating loss | (15,540) | (29,851) | (39,407) | |||
Interest expense | 607 | 707 | 1,001 | |||
Other (income) expense, net | (3,538) | (1,839) | (905) | |||
Income (loss) before income taxes | (12,609) | (28,719) | (39,503) | |||
Total expenditures for property, plant and equipment | 361 | 716 | 11,569 | |||
Intangible assets, net | 1,121 | 401 | 1,028 | 1,121 | ||
Total assets | $ 166,406 | $ 129,202 | $ 136,422 | $ 166,406 |
Subsequent Events (Details)
Subsequent Events (Details) $ in Millions | 2 Months Ended | ||
Mar. 04, 2022USD ($)lease | Dec. 31, 2021USD ($) | Dec. 31, 2020USD ($) | |
Subsequent Event [Line Items] | |||
Operating lease aggregate commitments | |||
Subsequent Event | |||
Subsequent Event [Line Items] | |||
Cash paid to acquire a business | $ 2.7 | ||
Real estate operating lease agreements term | 3 years | ||
Operating lease aggregate commitments | $ 0.6 | ||
Number of real estate operating lease agreements entered into | lease | 2 |