pump-20220630

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

______________________________

FORM 10-Q

______________________________


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

For the quarterly period ended June 30, 2022


☐			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number: 001-38035

______________________________

ProPetro Holding Corp.

(Exact name of registrant as specified in its charter)

______________________________


Delaware						26-3685382
(State or other jurisdiction of incorporation or organization)						(I.R.S. Employer Identification No.)

1706 South Midkiff,

Midland, Texas 79701

(Address of principal executive offices)

(432) 688-0012

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, par value $0.001 per share	PUMP	New York Stock Exchange
Preferred Stock Purchase Rights	N/A	New York Stock Exchange

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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

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

The number of the registrant’s common shares, par value $0.001 per share, outstanding at July 31, 2022, was 104,344,370.

PROPETRO HOLDING CORP.

TABLE OF CONTENTS


		Page
	Cautionary Note Regarding Forward-Looking Statements	ii

PART I – FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
	Condensed Consolidated Balance Sheets as of June 30 , 2022 and December 31, 2021	1
	Condensed Consolidated Statements of Operations for the three and six months ended June 3 0 , 2022 and 2021	2
	Condensed Consolidated Statements of Shareholders' Equity for the three and six months ended June 3 0 , 2022 and 2021	3
	Condensed Consolidated Statements of Cash Flows for the six months ended June 30 , 2022 and 2021	4
	Notes to Condensed Consolidated Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	20
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	32
Item 4.	Controls and Procedures	33

PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	34
Item 1A.	Risk Factors	34
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	34
Item 3.	Defaults Upon Senior Securities	34
Item 4.	Mine Safety Disclosures	34
Item 5.	Other Information	34
Item 6.	Exhibits	35
	Signatures	36

-i-

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q (this "Form 10-Q") contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities and Exchange Act of 1934, as amended (the "Exchange Act"). All statements other than statements of historical facts contained in this Form 10-Q are forward-looking statements. Forward-looking statements are all statements other than statements of historical facts, and give our expectations or forecasts of future events as of the effective date of this Form 10-Q. Words such as "may," "could," "plan," "project," "budget," "predict," "pursue," "target," "seek," "objective," "believe," "expect," "anticipate," "intend," "estimate," "will," "should" and similar expressions are generally to identify forward-looking statements. These statements include, but are not limited to statements about our business strategy, industry, future profitability and future capital expenditures. Such statements are subject to risks and uncertainties, many of which are difficult to predict and generally beyond our control, that could cause actual results to differ materially from those implied or projected by the forward-looking statements. Factors that could cause our actual results to differ materially from those contemplated by such forward-looking statements include:

•the severity and duration of current world health events and armed conflict, including the coronavirus ("COVID-19") pandemic and the Russian-Ukraine war and associated repercussions to supply and demand for oil and gas and the economy generally;

•the actions taken by the members of the Organization of the Petroleum Exporting Countries ("OPEC") and Russia (together with OPEC and other allied producing countries, "OPEC+") with respect to oil production levels and announcements of potential changes in such levels, including the ability of the OPEC+ countries to agree on and comply with supply limitations;

•actions taken by the Biden Administration, such as executive orders or new regulations, that may negatively impact the future production of oil and natural gas in the United States and may adversely affect our future operations;

•the level of production and resulting market prices for crude oil, natural gas and other hydrocarbons;

•changes in general economic and geopolitical conditions, including the rate of inflation and potential economic recession;

•the effects of existing and future laws and governmental regulations (or the interpretation thereof) on us and our customers;

•cost increases and supply chain constraints related to our services;

•competitive conditions in our industry;

•our ability to attract and retain employees;

•changes in the long-term supply of, and demand for, oil and natural gas;

•actions taken by our customers, suppliers, competitors and third-party operators and the possible loss of customers or work to our competitors;

•technological changes, including lower emissions oilfield services equipment and similar advancements;

•changes in the availability and cost of capital;

•our ability to successfully implement our business plan;

•large or multiple customer defaults, including defaults resulting from actual or potential insolvencies;

•the effects of consolidation on our customers or competitors;

•the price and availability of debt and equity financing (including changes in interest rates) for the Company and our customers;

•our ability to complete growth projects on time and on budget;

•operational challenges relating to the COVID-19 pandemic and efforts to mitigate the spread of the virus, including logistical challenges, protecting the health and well-being of our employees, remote work arrangements, performance of contracts and supply chain disruptions;

•changes in our tax status;

•regulatory and related policy actions intended by federal, state and/or local governments to reduce fossil fuel use and associated carbon emissions, or to drive the substitution of renewable forms of energy for oil and gas, may over time reduce demand for oil and gas and therefore the demand for our services;

-ii-

•new or expanded regulations that materially limit our customers’ access to federal and state lands for oil and gas development, thereby reducing demand for our services in the affected areas;

•growing demand for electric vehicles that result in reduced demand for gasoline and therefore the demand for our services;

•our ability to successfully implement technological developments and enhancements, including our new Tier IV DGB equipment, and other lower-emissions equipment we may acquire or that may be sought by our customers;

•operating hazards, natural disasters, weather-related delays, casualty losses and other matters beyond our control, which risks may be self-insured, or may not be fully covered under our insurance programs;

•acts of terrorism, war or political or civil unrest in the United States or elsewhere;

•the effects of current and future litigation, including the Logan Lawsuit; and

•the potential impact on our business and stock price of any announcements regarding the Logan Lawsuit.

Whether actual results and developments will conform with our expectations and predictions contained in forward-looking statements is subject to a number of risks and uncertainties which could cause actual results to differ materially from such expectations and predictions, including, without limitation, in addition to those specified in the text surrounding such statements, the risks described under Part II, Item 1A, "Risk Factors" in this Form 10-Q and elsewhere throughout this report, the risks described under Part I, Item 1A, "Risk Factors" in our Form 10-K for the year ended December 31, 2021, filed with the SEC (the "Form 10-K") and elsewhere throughout that report, and other risks, many of which are beyond our control.

Readers are cautioned not to place undue reliance on our forward-looking statements, which are made as of the date of this Form 10-Q. We do not undertake, and expressly disclaim, any duty to update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise, except as required by applicable securities laws. Investors are also advised to carefully review and consider the various risks and other disclosures discussed in our SEC reports, including the risk factors described in the Form 10-K.

-iii-

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)

(Unaudited)


	June 30, 2022		December 31, 2021
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	69,789	$	111,918
Accounts receivable - net of allowance for credit losses of $217 and $217, respectively	182,026		128,148
Inventories	3,491		3,949
Prepaid expenses	3,493		6,752
Other current assets	202		297
Total current assets	259,001		251,064
PROPERTY AND EQUIPMENT - net of accumulated depreciation	806,513		808,494
OPERATING LEASE RIGHT-OF-USE ASSETS	755		409
OTHER NONCURRENT ASSETS:
Other noncurrent assets	1,354		1,269
Total other noncurrent assets	1,354		1,269
TOTAL ASSETS	$	1,067,623	$	1,061,236

LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	170,145	$	152,649
Operating lease liabilities	588		369
Accrued and other current liabilities	22,925		20,767
Total current liabilities	193,658		173,785
DEFERRED INCOME TAXES	56,732		61,052
NONCURRENT OPERATING LEASE LIABILITIES	197		97
Total liabilities	250,587		234,934
COMMITMENTS AND CONTINGENCIES (Note 10)
SHAREHOLDERS’ EQUITY:
Preferred stock, $0.001 par value, 30,000,000 shares authorized, none issued, respectively	—		—
Common stock, $0.001 par value, 200,000,000 shares authorized, 104,308,413 and 103,437,177 shares issued, respectively	104		103
Additional paid-in capital	856,605		844,829
Accumulated deficit	(39,673)		(18,630)
Total shareholders’ equity	817,036		826,302
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	1,067,623	$	1,061,236

See notes to condensed consolidated financial statements.

-1-

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
REVENUE - Service revenue	$	315,083	$	216,887	$	597,763	$	378,345
COSTS AND EXPENSES
Cost of services (exclusive of depreciation and amortization)	218,813		162,837		416,083		286,215
General and administrative (inclusive of stock-based compensation)	25,135		17,529		56,842		37,731
Depreciation and amortization	31,462		33,243		63,317		66,721
Impairment expense	57,454		—		57,454		—
Loss on disposal of assets	22,485		15,025		38,603		28,076
Total costs and expenses	355,349		228,634		632,299		418,743
OPERATING INCOME (LOSS)	(40,266)		(11,747)		(34,536)		(40,398)
OTHER INCOME (EXPENSE):
Interest expense	(669)		(159)		(803)		(335)
Other income (expense)	6		(302)		10,364		1,487
Total other income (expense)	(663)		(461)		9,561		1,152
INCOME (LOSS) BEFORE INCOME TAXES	(40,929)		(12,208)		(24,975)		(39,246)
INCOME TAX (EXPENSE) BENEFIT	8,069		3,697		3,932		10,360
NET INCOME (LOSS)	$	(32,860)	$	(8,511)	$	(21,043)	$	(28,886)

NET INCOME (LOSS) PER COMMON SHARE:
Basic	$	(0.32)	$	(0.08)	$	(0.20)	$	(0.28)
Diluted	$	(0.32)	$	(0.08)	$	(0.20)	$	(0.28)

WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic	104,236		102,398		103,961		101,976
Diluted	104,236		102,398		103,961		101,976

See notes to condensed consolidated financial statements.

-2-

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY

(In thousands)

(Unaudited)


	Six Months Ended June 30, 2022
	Common Stock
	Shares	Amount		Additional Paid-In Capital		Accumulated Deficit		Total
BALANCE - January 1, 2022	103,437	$	103	$	844,829	$	(18,630)	$	826,302
Stock-based compensation cost	—	—		11,364		—		11,364
Issuance of equity awards, net	562	1		419		—		420
Tax withholdings paid for net settlement of equity awards	—	—		(2,691)		—		(2,691)
Net income (loss)	—	—		—		11,817		11,817
BALANCE - March 31, 2022	103,999	$	104	$	853,921	$	(6,813)	$	847,212
Stock-based compensation cost	—	—		3,458		—		3,458
Issuance of equity awards, net	309	—		321		—		321
Tax withholdings paid for net settlement of equity awards	—	—		(1,095)		—		(1,095)
Net income (loss)	—	—		—		(32,860)		(32,860)
BALANCE - June 30, 2022	104,308	$	104	$	856,605	$	(39,673)	$	817,036


	Six Months Ended June 30, 2021
	Common Stock
	Shares	Amount		Additional Paid-In Capital		Retained Earnings		Total
BALANCE - January 1, 2021	100,913	$	101	$	835,115	$	35,555	$	870,771
Stock-based compensation cost	—	—		2,487		—		2,487
Issuance of equity awards, net	1,145	1		(1)		—		—
Tax withholdings paid for net settlement of equity awards	—	—		(5,614)		—		(5,614)
Net income (loss)	—	—		—		(20,375)		(20,375)
BALANCE - March 31, 2021	102,058	$	102	$	831,987	$	15,180	$	847,269
Stock-based compensation cost	—	—		2,909		—		2,909
Issuance of equity awards, net	1,169	1		(1)		—		—
Tax withholdings paid for net settlement of equity awards	—	—		(159)		—		(159)
Proceeds from exercise of stock awards	—	—		3,235		—		3,235
Net income (loss)	—	—		—		(8,511)		(8,511)
BALANCE - June 30, 2021	103,227	$	103	$	837,971	$	6,669	$	844,743

See notes to condensed consolidated financial statements.

-3-

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)


	Six Months Ended June 30,
	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	(21,043)	$	(28,886)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	63,317		66,721
Impairment expense	57,454		—
Deferred income tax expense (benefit)	(4,321)		(10,360)
Amortization of deferred debt issuance costs	655		269
Stock-based compensation	14,822		5,396
Provision for credit losses	—		140
Loss on disposal of assets	38,603		28,076
Changes in operating assets and liabilities:
Accounts receivable	(53,878)		(53,762)
Other current assets	561		325
Inventories	457		89
Prepaid expenses	3,343		7,711
Accounts payable	(426)		44,933
Accrued and other current liabilities	3,764		828
Net cash provided by operating activities	103,308		61,480
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(144,519)		(52,187)
Proceeds from sale of assets	2,951		1,267
Net cash used in investing activities	(141,568)		(50,920)
CASH FLOWS FROM FINANCING ACTIVITIES:
Repayments of insurance financing	—		(4,093)
Payment of debt issuance costs	(824)		—
Proceeds from exercise of equity awards	741		3,235
Tax withholdings paid for net settlement of equity awards	(3,786)		(5,773)
Net cash used in financing activities	(3,869)		(6,631)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(42,129)		3,929
CASH AND CASH EQUIVALENTS - Beginning of period	111,918		68,772
CASH AND CASH EQUIVALENTS - End of period	$	69,789	$	72,701

See notes to condensed consolidated financial statements.

-4-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 - Basis of Presentation

The accompanying condensed consolidated financial statements of ProPetro Holding Corp. and its subsidiary (the "Company," "we," "us" or "our") have been prepared in accordance with the requirements of the U.S. Securities and Exchange Commission ("SEC") for interim financial information and do not include all of the information and footnotes required by accounting principles generally accepted in the United States of America ("GAAP") for annual financial statements. Those adjustments (which consisted of normal recurring accruals) that are, in the opinion of management, necessary for a fair presentation of the results of the interim periods have been made. Results of operations for such interim periods are not necessarily indicative of the results of operations for a full year due to changes in market conditions and other factors. The condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto for the year ended December 31, 2021, included in our Form 10-K filed with the SEC (our "Form 10-K").

Revenue Recognition

The Company’s services are sold based upon contracts with customers. The Company recognizes revenue when it satisfies a performance obligation by transferring control over a product or service to a customer. The following is a description of the principal activities, aggregated into our one reportable segment—"Pressure Pumping," and "all other" category, from which the Company generates its revenue.

Pressure Pumping — Pressure pumping consists of downhole pumping services, which includes hydraulic fracturing (inclusive of acidizing services) and cementing.

Hydraulic fracturing is a well-stimulation technique intended to optimize hydrocarbon flow paths during the completion phase of shale wellbores. The process involves the injection of water, sand and chemicals under high pressure into shale formations. Our hydraulic fracturing contracts with our customers have one performance obligation, which is the contracted total stages, satisfied over time. We recognize revenue over time using a progress output, unit-of-work performed method, which is based on the agreed fixed transaction price and actual stages completed. We believe that recognizing revenue based on actual stages completed faithfully depicts how our hydraulic fracturing services are transferred to our customers over time. In addition, certain of our hydraulic fracturing equipment is entitled to reservation or idle fee charges if a customer were to reserve or idle committed hydraulic fracturing equipment. The Company recognizes revenue related to idle or reservation fee charges on a daily basis or monthly as the performance obligations are met.

Acidizing, which is part of our hydraulic fracturing operating segment, involves a well-stimulation technique where acid or similar chemicals are injected under pressure into formations to form or expand fissures. Our acidizing contracts have one performance obligation, satisfied at a point-in-time, upon completion of the contracted service or sale of the acid or chemical when control is transferred to the customer. Jobs for these services are typically short term in nature, with most jobs completed in less than a day. We recognize acidizing revenue at a point-in-time, upon completion of the performance obligation.

Our cementing services use pressure pumping equipment to deliver a slurry of liquid cement that is pumped down a well between the casing and the borehole. Our cementing contracts have one performance obligation, satisfied at a point-in-time, upon completion of the contracted service when control is transferred to the customer. Jobs for these services are typically short term in nature, with most jobs completed in less than a day. We recognize cementing revenue at a point-in-time, upon completion of the performance obligation.

The transaction price for each performance obligation for all our pressure pumping services is fixed per our contracts with our customers.

All Other— All other consists of coiled tubing operations, which are downhole well completion/remedial services. The performance obligation for these services has a fixed transaction price which is satisfied at a point-in-time upon completion of the service when control is transferred to the customer. Accordingly, we recognize revenue at a point-in-time, upon completion of the service and transfer of control to the customer.

Accounts Receivable

Accounts receivables are stated at the amount billed and billable to customers. At June 30, 2022, and December 31, 2021, accrued revenue (unbilled receivable) included as part of our accounts receivable was $43.2 million and $19.4 million,

-5-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 - Basis of Presentation (Continued)

respectively. At June 30, 2022, the transaction price allocated to the remaining performance obligation for our partially completed hydraulic fracturing operations was $36.8 million, which is expected to be completed and recognized within one month following the current period balance sheet date, in our pressure pumping reportable segment.

Allowance for Credit Losses

As of June 30, 2022, the Company had $0.2 million allowance for credit losses. Our allowance for credit losses is based on the evaluation of both our historic collection experience and the expected impact of any potential deteriorating economic conditions in the oil and gas industry. We evaluated the historic loss experience on our accounts receivable and also separately considered customers with receivable balances that could be negatively impacted by current economic developments and market conditions. While the Company has not experienced significant credit losses in the past and has not yet seen material changes to the payment patterns of its customers, the Company cannot predict with any certainty the degree to which the impacts of the COVID-19 pandemic, including the potential impact of periodically adjusted borrowing base limits, level of hedged production, or unforeseen well shut-downs may affect the ability of its customers to timely pay receivables when due. Accordingly, in future periods, the Company may revise its estimates of expected credit losses.

The table below shows a summary of allowance for credit losses during the six months ended June 30, 2022:


(in thousands)

Balance - January 1, 2022	$	217
Provision for credit losses during the period	—
Write-off during the period	—
Balance - June 30, 2022	$	217

Note 2 - Recently Issued Accounting Standards

Recently Issued Accounting Standards Adopted in 2022

In March 2020, the Financial Accounting Standards Board ("FASB") issued ASU No. 2020-04, Reference Rate Reform, which provides temporary optional guidance to companies impacted by the transition away from the London Interbank Offered Rate ("LIBOR"). The guidance provides certain expedients and exceptions to applying GAAP in order to lessen the potential accounting burden when contracts, hedging relationships, and other transactions that reference LIBOR as a benchmark rate are modified. This guidance is effective upon issuance and expires on December 31, 2022. Effective January 1, 2022, we adopted this guidance, and the adoption did not materially affect the Company’s condensed consolidated financial statements.

Note 3 - Fair Value Measurement

Fair value ("FV") is defined as the price that would be received to sell an asset or paid to transfer a liability (i.e., the "exit price") in an orderly transaction between market participants at the measurement date.

In determining fair value, the Company uses various valuation approaches and establishes a hierarchy for inputs used in measuring fair value that maximizes the use of relevant observable inputs and minimizes the use of unobservable inputs by requiring that the most observable inputs be used, when available. Observable inputs are inputs that market participants would use in pricing the asset or liability developed based on market data obtained from sources independent of the Company. Unobservable inputs are inputs that reflect the Company's assumptions about the assumptions other market participants would use in pricing the asset or liability developed based on the best information available in the circumstances. The hierarchy is broken down into three levels based on the observability of inputs as follows:

Level 1 — Valuations based on quoted prices in active markets for identical assets or liabilities that the Company has the ability to access. Valuation adjustments and block discounts are not applied to Level 1 instruments. Since valuations are based on quoted prices that are readily and regularly available in an active market, valuation of these instruments does not entail a significant degree of judgment.

Level 2 — Valuations based on one or more quoted prices in markets that are not active or for which all significant inputs are observable, either directly or indirectly.

-6-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 3 - Fair Value Measurement (Continued)

Level 3 — Valuations based on inputs that are unobservable and significant to the overall fair value measurement.

A financial instrument's categorization within the valuation hierarchy is based upon the lowest level of input that is significant to the fair value measurement. The Company's assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability.

Assets and Liabilities Measured at Fair Value on a Recurring Basis

Our financial instruments include cash and cash equivalents, accounts receivable, accounts payable, accrued and other current liabilities, and long-term debt (if any). The estimated fair value of our financial instruments at June 30, 2022 and December 31, 2021, approximated or equaled their carrying values as reflected in our condensed consolidated balance sheets.

Assets Measured at Fair Value on a Nonrecurring Basis

Assets measured at fair value on a nonrecurring basis as of June 30, 2022 and December 31, 2021, respectively, are set forth below:


(In thousands)
			Estimated fair value measurements
	Balance		Quoted prices in active market (Level 1)		Significant other observable inputs (Level 2)		Significant other unobservable inputs (Level 3)		Total gains (losses)
June 30, 2022:
Property and equipment, net	$	11,341	$	—	$	—	$	11,341	$	(57,454)
December 31, 2021:
Property and equipment, net	$	—	$	—	$	—	$	—	$	—

Whenever events or circumstances indicate that the carrying value of long-lived assets may not be recoverable, the Company reviews the carrying value of long‑lived assets, such as property and equipment and other assets to determine if they are recoverable. If any long‑lived assets are determined to be unrecoverable, an impairment expense is recorded in the period. As part of the quarterly evaluation for the three months ended June 30, 2022, the Company determined after evaluating existing and new information available that the timely commercialization of its DuraStim® assets, which is included as part of our hydraulic fracturing operations, is no longer reasonably certain, and as such, certain DuraStim® assets may not be recoverable. Our DuraStim® assets are comprised of DuraStim® hydraulic fracturing pumps that utilize electric pressure pumping technology and other ancillary equipment. The Company's DuraStim® technology was first operationally tested at a customer wellsite in 2019, and the DuraStim® hydraulic fracturing pumps' performance did not meet the manufacturer's specifications or our expectations. Although the Company's equipment manufacturer was able to slightly improve the operational performance of the DuraStim® hydraulic fracturing pumps in subsequent tests performed in 2020 and 2021, the overall performance was not consistent with our customers' demands. Given current market conditions, incremental development cost, continued supply chain disruptions, inflation, and other factors impacting further development of our DuraStim® electric technology, the Company does not expect to deploy the equipment in its current form. During the three months ended June 30, 2022, the Company performed an impairment analysis on the DuraStim® hydraulic fracturing pumps that were deemed not recoverable, and compared the carrying value of the DuraStim® hydraulic fracturing pumps with its estimated fair value. The Company determined that the DuraStim® hydraulic fracturing pumps were impaired as the carrying value of the DuraStim® hydraulic fracturing pumps was greater than its estimated fair value. Accordingly, an impairment expense of approximately $57.5 million was recorded, in our pressure pumping reportable segment, for the three months ended June 30, 2022. At June 30, 2022, the estimated fair value of the DuraStim® hydraulic fracturing pumps of $11.3 million was determined using the cost approach, which represents a Level 3 in the fair value measurement hierarchy. Our fair value estimates required us to use significant other unobservable inputs, including assumptions related to replacement cost, among others. The carrying value of our DuraStim® hydraulic fracturing pumps prior to the impairment expense was approximately $68.8 million. No impairment of property and equipment was recorded during the six months ended June 30, 2021.

-7-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 4 - Long-Term Debt

Asset-Based Loan ("ABL") Credit Facility

Our revolving credit facility, as amended in 2018, had a total borrowing capacity of $300.0 million (subject to the borrowing base limit), with a maturity date of December 19, 2023. The revolving credit facility had a borrowing base of 85% of monthly eligible accounts receivable less customary reserves, as redetermined monthly. The revolving credit facility, included a springing fixed charge coverage ratio to apply when excess availability was less than the greater of (i) 10% of the lesser of the facility size or the borrowing base or (ii) $22.5 million. Borrowings under this revolving credit facility accrued interest based on a three-tier pricing grid tied to availability, and we had the option to elect for loans to be based on either LIBOR or base rate, plus the applicable margin, which ranged from 1.75% to 2.25% for LIBOR loans and 0.75% to 1.25% for base rate loans, with a LIBOR floor of zero.

Effective April 13, 2022, the Company entered into an amendment and restatement of its revolving credit facility (as amended and restated, "ABL Credit Facility"). The ABL Credit Facility decreased the borrowing capacity to $150.0 million (subject to the Borrowing Base (as defined below) limit), with the maturity date extended to April 13, 2027. The ABL Credit Facility has a borrowing base of 85% to 90%, depending on the credit ratings of our accounts receivable counterparties, of monthly eligible accounts receivable less customary reserves (the "Borrowing Base"), as redetermined monthly. The Borrowing Base as of June 30, 2022, was approximately $120.5 million. The ABL Credit Facility includes a springing fixed charge coverage ratio to apply when excess availability is less than the greater of (i) 10% of the lesser of the facility size or the Borrowing Base or (ii) $10.0 million. Under this facility we are required to comply, subject to certain exceptions and materiality qualifiers, with certain customary affirmative and negative covenants, including, but not limited to, covenants pertaining to our ability to incur liens, indebtedness, changes in the nature of our business, mergers and other fundamental changes, disposal of assets, investments and restricted payments, amendments to our organizational documents or accounting policies, prepayments of certain debt, dividends, transactions with affiliates, and certain other activities. Borrowings under the ABL Credit Facility are secured by a first priority lien and security interest in substantially all assets of the Company. Borrowings under the ABL Credit Facility accrue interest based on a three-tier pricing grid tied to availability, and we may elect for loans to be based on either the Secured Overnight Financing Rate ("SOFR") or the base rate, plus the applicable margin, which ranges from 1.50% to 2.00% for SOFR loans and 0.50% to 1.00% for base rate loans.

The loan origination costs relating to the ABL Credit Facility are classified as an asset in our balance sheet. There were no borrowings under the revolving credit facility as of June 30, 2022 and December 31, 2021.

Note 5 - Reportable Segment Information

The Company has three operating segments for which discrete financial information is readily available: hydraulic fracturing (inclusive of acidizing), cementing and coiled tubing. These operating segments represent how the Chief Operating Decision Maker evaluates performance and allocates resources.

In December 2021, the Company disposed of two turbine generators included in our pressure pumping reportable segment for total cash proceeds of approximately $36.0 million. The net book value of the two turbines prior to the disposal was approximately $39.5 million, resulting in loss on disposal of approximately $3.5 million.

In accordance with the FASB Accounting Standards Codification ("ASC") 280—Segment Reporting, the Company has one reportable segment (pressure pumping) comprised of the hydraulic fracturing and cementing operating segments. The coiled tubing operating segment and corporate administrative expense (inclusive of our total income tax expense (benefit), other (income) and expense and interest expense) are included in the "all other" category in the table below. Total corporate administrative expense for the three and six months ended June 30, 2022 was $7.7 million and $25.0 million, respectively. Total corporate administrative expense for the three and six months ended June 30, 2021 was $6.5 million and $11.6 million, respectively.

Our hydraulic fracturing operating segment revenue approximated 92.9% and 93.2% of our pressure pumping revenue during the three and six months ended June 30, 2022, respectively. During the three and six months ended June 30, 2021, our hydraulic fracturing operating segment revenue approximated 93.7% and 93.5% of our pressure pumping revenue, respectively.

Inter-segment revenues are not material and are not shown separately in the table below.

-8-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 5 - Reportable Segment Information (Continued)

The Company manages and assesses the performance of the reportable segment by its adjusted EBITDA (earnings before other income (expense), interest expense, income taxes, depreciation and amortization, stock-based compensation expense, severance and related expense, impairment expense, (gain)/loss on disposal of assets and other unusual or nonrecurring expenses or (income)).

A reconciliation from segment level financial information to the consolidated statement of operations is provided in the table below (in thousands):


	Three Months Ended June 30, 2022
	Pressure Pumping		All Other		Total
Service revenue	$	309,445	$	5,638	$	315,083
Adjusted EBITDA	$	86,291	$	(10,344)	$	75,947
Depreciation and amortization	$	30,528	$	934	$	31,462
Capital expenditures	$	83,170	$	5,911	$	89,081
Total assets at June 30, 2022	$	1,025,044	$	42,579	$	1,067,623


	Three Months Ended June 30, 2021
	Pressure Pumping		All Other		Total
Service revenue	$	213,461	$	3,426	$	216,887
Adjusted EBITDA	$	46,826	$	(11,133)	$	35,693
Depreciation and amortization	$	32,256	$	987	$	33,243
Capital expenditures	$	30,744	$	29	$	30,773
Total assets December 31, 2021	$	1,023,037	$	38,199	$	1,061,236


	Six Months Ended June 30, 2022
	Pressure Pumping		All Other		Total
Service revenue	$	586,557	$	11,206	$	597,763
Adjusted EBITDA	$	163,285	$	(20,805)	$	142,480
Depreciation and amortization	$	61,459	$	1,858	$	63,317
Capital expenditures	$	154,773	$	6,036	$	160,809
Total assets at June 30, 2022	$	1,025,044	$	42,579	$	1,067,623


	Six Months Ended June 30, 2021
	Pressure Pumping		All Other		Total
Service revenue	$	371,652	$	6,693	$	378,345
Adjusted EBITDA	$	78,697	$	(22,988)	$	55,709
Depreciation and amortization	$	64,770	$	1,951	$	66,721
Capital expenditures	$	60,766	$	2,334	$	63,100
Total assets December 31, 2021	$	1,023,037	$	38,199	$	1,061,236

-9-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 5 - Reportable Segment Information (Continued)

Reconciliation of net income (loss) to adjusted EBITDA (in thousands):


	Three Months Ended June 30, 2022
	Pressure Pumping		All Other		Total
Net income (loss)	$	(24,392)	$	(8,468)	$	(32,860)
Depreciation and amortization	30,528		934		31,462
Impairment expense	57,454		—		57,454
Interest expense	—		669		669
Income tax benefit	—		(8,069)		(8,069)
Loss (gain) on disposal of assets	22,680		(195)		22,485
Stock-based compensation	—		3,458		3,458
Other income	—		(6)		(6)
Other general and administrative expense(1)	21		1,333		1,354
Adjusted EBITDA	$	86,291	$	(10,344)	$	75,947

	Three Months Ended June 30, 2021
	Pressure Pumping		All Other		Total
Net income (loss)	$	(809)	$	(7,702)	$	(8,511)
Depreciation and amortization	32,256		987		33,243
Interest expense	—		159		159
Income tax benefit	—		(3,697)		(3,697)
Loss (gain) on disposal of assets	15,379		(354)		15,025
Stock-based compensation	—		2,909		2,909
Other expense	—		302		302
Other general and administrative expense, (net)(1)	—		(3,737)		(3,737)
Adjusted EBITDA	$	46,826	$	(11,133)	$	35,693

-10-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 5 - Reportable Segment Information (Continued)


	Six Months Ended June 30, 2022
	Pressure Pumping		All Other		Total
Net income (loss)	$	4,977	$	(26,020)	$	(21,043)
Depreciation and amortization	61,459		1,858		63,317
Impairment expense	57,454		—		57,454
Interest expense	—		803		803
Income tax benefit	—		(3,932)		(3,932)
Loss (gain) on disposal of assets	39,101		(498)		38,603
Stock-based compensation	—		14,822		14,822
Other income(2)	—		(10,364)		(10,364)
Other general and administrative expense (1)	294		2,526		2,820
Adjusted EBITDA	$	163,285	$	(20,805)	$	142,480

	Six Months Ended June 30, 2021
	Pressure Pumping		All Other		Total
Net income (loss)	$	(14,484)	$	(14,402)	$	(28,886)
Depreciation and amortization	64,770		1,951		66,721
Interest expense	—		335		335
Income tax benefit	—		(10,360)		(10,360)
Loss (gain) on disposal of assets	28,411		(335)		28,076
Stock-based compensation	—		5,396		5,396
Other income	—		(1,487)		(1,487)
Other general and administrative expense (1)	—		(4,698)		(4,698)
Retention bonus and severance expense	—		612		612
Adjusted EBITDA	$	78,697	$	(22,988)	$	55,709

(1)Other general and administrative expense, (net of reimbursement from insurance carriers) primarily relates to nonrecurring professional fees paid to external consultants in connection with our audit committee review, SEC investigation, shareholder litigation and other legal matters, net of insurance recoveries. During the three and six months ended June 30, 2022, we received reimbursement of approximately $2.4 million and $3.5 million, respectively, from our insurance carriers in connection with the SEC investigation and shareholder litigation. During the three and six months ended June 30, 2021, we received reimbursement of approximately $5.1 million and $6.7 million, respectively.

(2)Includes $10.7 million of net tax refund (net of advisory fees) received in March 2022 from the Texas Comptroller of Public Accounts in connection with limited sales, excise, and use tax beginning July 1, 2015 through December 31, 2018.

-11-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 6 - Net Income (Loss) Per Share

Basic net income (loss) per common share is computed by dividing the net income (loss) relevant to the common stockholders by the weighted average number of common shares outstanding during the period. Diluted net income (loss) per common share uses the same net income (loss) divided by the sum of the weighted average number of shares of common stock outstanding during the period, plus dilutive effects of options, performance and restricted stock units outstanding during the period calculated using the treasury method and the potential dilutive effects of preferred stocks (if any) calculated using the if-converted method.

The table below shows the calculations for the three and six months ended June 30, 2022 and 2021, (in thousands, except for per share data):


	Three Months Ended June 30,
	2022		2021
Numerator (both basic and diluted)
Net income (loss) relevant to common stockholders	$	(32,860)	$	(8,511)

Denominator
Denominator for basic income (loss) per share	104,236		102,398
Dilutive effect of stock options	—		—
Dilutive effect of performance share units	—		—
Dilutive effect of restricted stock units	—		—
Denominator for diluted income (loss) per share	104,236		102,398

Basic income (loss) per common share	$	(0.32)	$	(0.08)
Diluted income (loss) per common share	$	(0.32)	$	(0.08)


	Six Months Ended June 30,
	2022		2021
Numerator (both basic and diluted)
Net income (loss) relevant to common stockholders	$	(21,043)	$	(28,886)

Denominator
Denominator for basic income (loss) per share	103,961		101,976
Dilutive effect of stock options	—		—
Dilutive effect of performance share units	—		—
Dilutive effect of restricted stock units	—		—
Denominator for diluted income (loss) per share	103,961		101,976

Basic income (loss) per share	$	(0.20)	$	(0.28)
Diluted income (loss) per share	$	(0.20)	$	(0.28)

-12-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

As shown in the table below, the following stock options, restricted stock units and performance stock units outstanding as of June 30, 2022, have not been included in the calculation of diluted income (loss) per common share for the three and six months ended June 30, 2022 and 2021 because they will be anti-dilutive to the calculation of diluted net income (loss) per common share:


(In thousands)	Three Months Ended June 30,
	2022	2021
Stock options	587	995
Restricted stock units	1,207	1,380
Performance stock units	1,788	1,489
Total	3,582	3,864


(In thousands)	Six Months Ended June 30,
	2022	2021
Stock options	587	995
Restricted stock units	1,207	1,380
Performance stock units	1,788	1,489
Total	3,582	3,864

Note 7 - Stock-Based Compensation

Stock Options

There were no new stock option grants during the six months ended June 30, 2022. As of June 30, 2022, the aggregate intrinsic value for our outstanding stock options was $0.8 million, and the aggregate intrinsic value for our exercisable stock options was $0.8 million. The aggregate intrinsic value for the exercised stock options during the six months ended June 30, 2022 was approximately $1.9 million. The remaining exercise period for both the outstanding and exercisable stock options as of June 30, 2022 was approximately 3.0 years.

A summary of the stock option activity for the six months ended June 30, 2022 is presented below (in thousands, except for weighted average price):


	Number of Shares	Weighted Average Exercise Price
Outstanding at January 1, 2022	798	$	9.77
Granted	—	$	—
Exercised	(211)	$	3.52
Forfeited	—	$	—
Expired	—	$	—
Outstanding at June 30, 2022	587	$	12.02
Exercisable at June 30, 2022	587	$	12.02

Restricted Stock Units

During the six months ended June 30, 2022, we granted 631,233 restricted stock units ("RSUs") to employees, officers and directors pursuant to the ProPetro Holding Corp. 2020 Long Term Incentive Plan (the "2020 Incentive Plan"), which generally vest ratably over a three-year vesting period, in the case of awards to employees and officers, and generally vest in full after one year, in the case of awards to directors. RSUs are subject to restrictions on transfer and are generally subject to a risk of forfeiture if the award recipient ceases to be an employee or director of the Company prior to vesting of the award. Each RSU represents the right to receive one share of common stock. The grant date fair value of the RSUs is based on the closing

-13-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 7 - Stock-Based Compensation (Continued)

share price of our common stock on the date of grant. As of June 30, 2022, the total unrecognized compensation expense for all RSUs was approximately $10.6 million, and is expected to be recognized over a weighted average period of approximately 2.0 years.

On March 31, 2022, the Company modified the RSUs previously granted to a former officer in 2019, 2020 and 2021 to accelerate the vesting of such RSUs in connection with his separation agreement. As a result of this modification, we recorded an incremental stock expense of $1.3 million during the six months ended June 30, 2022.

The following table summarizes RSUs activity during the six months ended June 30, 2022 (in thousands, except for weighted average fair value):


	Number of Shares	Weighted Average Grant Date Fair Value
Outstanding at January 1, 2022	1,413	$	9.19
Granted	631	$	12.59
Vested	(819)	$	9.24
Forfeited	(18)	$	10.77
Canceled	—	$	—
Outstanding at June 30, 2022	1,207	$	10.91

Performance Share Units

During the six months ended June 30, 2022, we granted 327,939 performance share units ("PSUs") to certain key employees and officers as new awards under the 2020 Incentive Plan. Each PSU earned represents the right to receive either one share of common stock or, as determined by the administrator in its sole discretion, a cash amount equal to fair market value of one share of common stock or amount of cash on the day immediately preceding the settlement date. The actual number of shares of common stock that may be issued under the PSUs ranges from 0% up to a maximum of 200% of the target number of PSUs granted to the participant, based on our total shareholder return ("TSR") relative to a designated peer group, generally at the end of a three year period. In addition to the TSR conditions, vesting of the PSUs is generally subject to the recipient’s continued employment through the end of the applicable performance period. Compensation expense is recorded ratably over the corresponding requisite service period. The grant date fair value of PSUs is determined using a Monte Carlo probability model. Grant recipients do not have any shareholder rights until performance relative to the peer group has been determined following the completion of the performance period and shares have been issued.

In connection with a former officer’s separation agreement, on March 31, 2022, the Company modified the PSUs previously granted to such former officer in 2020 and 2021 to provide for deemed satisfaction of the service requirement applicable to such PSUs as of March 31, 2022, such that such PSUs shall remain outstanding and eligible to vest based on our TSR relative to a designated peer group over the applicable performance period. As a result of these modifications, we recorded an incremental stock expense of $3.7 million during the six months ended June 30, 2022.

-14-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 7 - Stock-Based Compensation (Continued)

The following table summarizes information about PSUs activity during the six months ended June 30, 2022 (in thousands, except for weighted average fair value):


Period Granted	Target Shares Outstanding at January 1, 2022		Target Shares Granted		Target Shares Vested		Target Shares Forfeited		Target Shares Outstanding at June 30, 2022
2019	126		—		(126)		—		—
2020	809		—		—		—		809
2021	651		—		—		—		651
2022	—		328		—		—		328
Total	1,586		328		(126)		—		1,788
Weighted Average FV Per Share	$	12.48	$	19.99	$	27.49	$	—	$	12.79

The total stock-based compensation expense for the six months ended June 30, 2022 and 2021 for all stock awards was $14.8 million and $5.4 million, respectively. The total unrecognized stock-based compensation expense as of June 30, 2022 was approximately $22.4 million, and is expected to be recognized over a weighted average period of approximately 2.0 years.

-15-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 8 - Related-Party Transactions

Operations and Maintenance Yards

The Company rents five yards from an entity, in which a director of the Company has an equity interest and the total annual rent expense for each of the five yards was approximately $0.03 million, $0.03 million, $0.1 million, $0.1 million, and $0.2 million, respectively.

Pioneer

On December 31, 2018, we consummated the purchase of certain pressure pumping assets and real property from Pioneer Natural Resources USA, Inc. ("Pioneer") and Pioneer Pumping Services (the "Pioneer Pressure Pumping Acquisition"). In connection with the Pioneer Pressure Pumping Acquisition, Pioneer received 16.6 million shares of our common stock and approximately $110.0 million in cash. On March 31, 2022, we entered into an amended and restated pressure pumping services agreement (the "A&R Pressure Pumping Services Agreement"), which was initially entered into in connection with the Pioneer Pressure Pumping Acquisition. The A&R Pressure Pumping Services Agreement was effective January 1, 2022 and continues through December 31, 2022. The A&R Pressure Pumping Services Agreement reduced the number of contracted fleets to six fleets from eight fleets, modified the pressure pumping scope of work and pricing mechanism for contracted fleets, and replaced the idle fees arrangement with equipment reservation fees (the "Reservation fees"). As part of the Reservation fees arrangement, the Company will be entitled to receive compensation for all eligible contracted fleets that are made available to Pioneer at the beginning of every quarter in 2022 through the term of the A&R Pressure Pumping Services Agreement.

Revenue from services provided to Pioneer (including idle fees and Reservation fees) accounted for approximately $115.2 million and $130.7 million of our total revenue during the three months ended June 30, 2022 and 2021, respectively. Revenue from services provided to Pioneer (including idle fees and Reservation fees) accounted for approximately $238.7 million and $217.0 million of our total revenue during the six months ended June 30, 2022 and 2021, respectively.

As of June 30, 2022, the total accounts receivable due from Pioneer, including estimated unbilled receivable for services we provided, amounted to approximately $69.0 million and the amount due to Pioneer was $0. As of December 31, 2021, the balance due from Pioneer for services we provided amounted to approximately $62.1 million and the amount due to Pioneer was $0.

-16-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 9 - Leases

Operating Leases

Description of Lease

In March 2013, we entered into a ten year real estate lease contract (the "Real Estate Lease") with a commencement date of April 1, 2013, as part of the expansion of our equipment yard. During the six months ended June 30, 2022 and 2021, the Company made lease payments of approximately $0.2 million and $0.1 million, respectively. The assets and liabilities under this contract are equally allocated between our cementing and coiled tubing segments. In addition to the contractual lease period, the contract includes an optional renewal of up to ten years, and in management's judgment the exercise of the renewal option is not reasonably assured. The contract does not include a residual value guarantee, covenants or financial restrictions. Further, the Real Estate Lease does not contain variability in payments resulting from either an index change or rate change.

We accounted for our Real Estate Lease as an operating lease. This conclusion resulted from the existence of the right to control the use of the assets throughout the lease term. We did not account for the land separately from the building of the Real Estate Lease because we concluded that the accounting effect was insignificant. As of June 30, 2022, the weighted average discount rate and remaining lease term was approximately 6.7% and 0.8 years, respectively.

As part of our expansion of our hydraulic fracturing equipment maintenance program, we entered into a two year maintenance facility real estate lease contract (the "Maintenance Facility Lease") with a commencement date of March 14, 2022. During the six months ended June 30, 2022, the Company made lease payments of approximately $0.1 million. In addition to the contractual lease period, the contract includes an optional renewal for three additional periods of one year each, and in management's judgment the exercise of the renewal option is not reasonably assured. The contract does not include a residual value guarantee, covenants or financial restrictions. Further, the Maintenance Facility Lease does not contain variability in payments resulting from either an index change or rate change.

We accounted for our Maintenance Facility Lease as an operating lease. Our assumptions resulted from the existence of the right to control the use of the assets throughout the lease term. We did not account for the land separately from the building of the Maintenance Facility Lease because we concluded that the accounting effect was insignificant. As of June 30, 2022, the weighted average discount rate and remaining lease term was approximately 3.4% and 1.7 years, respectively.

As of June 30, 2022, the total operating lease right-of-use asset cost was approximately $1.9 million, and accumulated amortization was approximately $1.1 million. As of December 31, 2021, our total operating lease right-of-use asset cost was approximately $1.2 million, and accumulated amortization was approximately $0.8 million. For the six months ended June 30, 2022 and 2021, we recorded operating lease cost of approximately $0.3 million and $0.2 million, respectively, in our statement of operations.

Maturity Analysis of Lease Liabilities

The maturity analysis of liabilities and reconciliation to undiscounted and discounted remaining future lease payments for our operating lease as of June 30, 2022 are as follows:



($ in thousands)	Totals
2022	$	360
2023	398
2024	50
Total undiscounted future lease payments	808
Less: amount representing interest	(23)
Present value of future lease payments (lease obligation)	$	785

The total cash paid for amounts included in the measurement of our operating lease liability during the six months ended June 30, 2022 was approximately $0.3 million. The non-cash lease obligation we recorded upon execution of the Maintenance Facility Lease was approximately $0.6 million. During the six months ended June 30, 2021, total cash paid for amounts included in the measurement of our operating lease liability was approximately $0.1 million.

-17-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 9 - Leases (Continued)

Short-Term Leases

We elected the practical expedient, consistent with ASC 842, to exclude leases with an initial term of twelve months or less ("short-term lease") from our balance sheet and continue to record short-term leases as a period expense. For the six months ended June 30, 2022 and 2021 our short-term lease expense was approximately $0.4 million and $0.3 million, respectively.

Note 10 - Commitments and Contingencies

Commitments

We entered into certain commitments for fixed assets, consumables and services incidental to the ordinary conduct of our business, generally for quantities required for our operations and at competitive market prices. These commitments are designed to assure sources of supply and are not expected to be in excess of normal requirements. At June 30, 2022, the total remaining lease commitments for all of our short-term leases and lodging commitments was approximately $2.5 million. In August 2022, we entered into a contractual arrangement with our equipment manufacturer to purchase and convert additional Tier IV DGB equipment, with total cost of approximately $43.0 million.

The Company enters into purchase agreements with its sand suppliers (the "Sand Suppliers") to secure supply of sand as part of its normal course of business. The agreements with the Sand Suppliers require that the Company purchase a minimum volume of sand, based primarily on a certain percentage of our sand requirements from our customers or in certain situations based on predetermined fixed minimum volumes, otherwise certain penalties ("shortfall fees") may be charged. The shortfall fee represents liquidated damages and is either a fixed percentage of the purchase price for the minimum volumes or a fixed price per ton of unpurchased volumes. Our agreements with the Sand Suppliers expire at different times prior to December 31, 2025. Our sand agreement with one of our Sand Suppliers has a one year take or pay commitment of $23.0 million that will expire on June 12, 2023. During the six months ended June 30, 2022 and 2021, no shortfall fee was recorded. However, one of our Sand Suppliers has filed a suit against us that includes claims related to alleged shortfall fees. The suit is in the early stages, and we are contesting the claims. While we cannot reasonably estimate the outcome of the matter at this time, in the opinion of management, the ultimate disposition of the action will not have a materially adverse effect on the Company.

As of June 30, 2022, the Company had issued letters of credit of approximately $5.0 million under the revolving credit facility in connection with the Company’s casualty insurance policy.

Contingent Liabilities

Legal Matters

In September 2019, a complaint, captioned Richard Logan, Individually and On Behalf of All Others Similarly Situated, Plaintiff, v. ProPetro Holding Corp., et al., (the "Logan Lawsuit"), was filed against the Company and certain of its then current and former officers and directors in the U.S. District Court for the Western District of Texas.

In July 2020, the Logan Lawsuit Lead Plaintiffs Nykredit Portefølje Administration A/S, Oklahoma Firefighters Pension and Retirement System, Oklahoma Law Enforcement Retirement System, Oklahoma Police Pension and Retirement System, and Oklahoma City Employee Retirement System, and additional named plaintiff Police and Fire Retirement System of the City of Detroit, individually and on behalf of a putative class of shareholders who purchased the Company’s common stock between March 17, 2017 and March 13, 2020, filed a third amended class action complaint in the U.S. District Court for the Western District of Texas, alleging violations of Sections 10(b) and 20(a) of the Exchange Act, as amended, and Rule l0b-5 promulgated thereunder, and Sections 11 and 15 of the Securities Act of 1933, as amended, based on allegedly inaccurate or misleading statements, or omissions of material facts, about the Company’s business, operations and prospects against the Company, certain former officers and current and former directors. On September 13, 2021, the Court partially granted and partially denied the motions to dismiss filed by the Company and the individual defendants. Discovery is still ongoing.

In May 2020, the U.S. District Court for the Western District of Texas consolidated two shareholder derivative lawsuits previously filed against the Company and certain of its current and former officers and directors into a single lawsuit captioned In re ProPetro Holding Corp. Derivative Litigation (the "Shareholder Derivative Lawsuit"). In August 2020, the plaintiffs in the Shareholder Derivative Lawsuit filed a consolidated complaint alleging (i) breaches of fiduciary duties, (ii) unjust enrichment and (iii) contribution. The plaintiffs did not quantify any alleged damages in their complaint but, in addition to attorneys’ fees and costs, they seek various forms of relief, including (i) damages sustained by the Company as a result of the alleged misconduct, (ii) punitive damages and (iii) equitable relief in the form of improvements to the Company’s governance and

-18-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 10 - Commitments and Contingencies (Continued)

controls. On September 15, 2021, the Court granted the Company's motion to dismiss the complaint in its entirety, without prejudice.

On November 19, 2021, the Company received a demand letter from a law firm representing a purported shareholder of the Company that previously filed the dismissed Shareholder Derivative Lawsuit. The demand letter alleged facts and claims substantially similar to the Shareholder Derivative Lawsuit. The Company's board of directors (the "Board") has constituted a committee to evaluate the demand letter and recommend a course of action to the Board, and the committee has retained counsel to assist with its review. The committee’s review is ongoing.

We are presently unable to predict the duration, scope or result of the Logan Lawsuit, or any other related lawsuit or investigation. As of June 30, 2022, no provision was made by the Company in connection with this pending lawsuit as the final outcome cannot be reasonably estimated.

Environmental and Equipment Insurance

The Company is subject to various federal, state and local environmental laws and regulations that establish standards and requirements for protection of the environment. The Company cannot predict the future impact of such standards and requirements, which are subject to change and can have retroactive effectiveness. The Company continues to monitor the status of these laws and regulations. Currently, the Company has not been fined, cited or notified of any environmental violations that would have a material adverse effect upon its financial position, liquidity or capital resources. However, management does recognize that by the very nature of the Company's business, material costs could be incurred in the near term to maintain compliance. The amount of such future expenditures is not determinable due to several factors, including the unknown magnitude of possible regulation or liabilities, the unknown timing and extent of the corrective actions which may be required, the determination of the Company's liability in proportion to other responsible parties and the extent to which such expenditures are recoverable from insurance or indemnification.

The Company is self-insured up to $10 million per occurrence for certain losses arising from or attributable to fire and/or explosion at the wellsites. No accrual was recorded in our financial statements in connection with this self-insurance strategy.

Regulatory Audits

In 2020, the Texas Comptroller of Public Accounts (the "Comptroller") commenced a routine audit of the Company's motor vehicle and other related fuel taxes for the periods of July 2015 through December 2020. As of June 30, 2022, the audit is still ongoing and the final outcome cannot be reasonably estimated.

In January 2022, we entered into a settlement agreement with the Comptroller for a $10.7 million tax refund, net of consulting fees, in connection with certain limited sales, excise and use tax for the audit period July 1, 2015 through December 31, 2018. The net refund to the Company of $10.7 million was recorded as part of other income in our statement of operations during the six months ended June 30, 2022. During the six months ended June 30, 2021, we recorded net refund of approximately $2.1 million.

In May 2022, the Company received a notification from the Comptroller that it will commence a routine audit of the Company's gross receipt taxes, which will routinely cover up to a four-year period. As of June 30, 2022, the audit is yet to commence, and as such, the final outcome cannot be reasonably estimated.

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ITEM 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

The financial information, discussion and analysis that follow should be read in conjunction with our consolidated financial statements and the related notes included in the Form 10-K as well as the financial and other information included therein.

Unless otherwise indicated, references in this "Management's Discussion and Analysis of Financial Condition and Results of Operations" to the "Company," "we," "our," "us" or like terms refer to ProPetro Holding Corp. and its subsidiary.

Overview

We are a Midland, Texas-based oilfield services company providing hydraulic fracturing and other complementary services to leading upstream oil and gas companies engaged in the exploration and production ("E&P") of North American oil and natural gas resources. Our operations are primarily focused in the Permian Basin, where we have cultivated longstanding customer relationships with some of the region's most active and well-capitalized E&P companies. The Permian Basin is widely regarded as one of the most prolific oil-producing areas in the United States, and we believe we are one of the largest providers of hydraulic fracturing services in the region by hydraulic horsepower ("HHP").

Our total available HHP as of June 30, 2022, was 1,315,000 HHP, which was comprised of 197,500 HHP of our Tier IV Dynamic Gas Blending ("DGB") equipment and 1,117,500 HHP of conventional Tier II equipment. Our fleet could range from approximately 50,000 to 80,000 HHP depending on the job design and customer demand at the wellsite. With the industry transition to lower emissions equipment and simultaneous hydraulic fracturing ("Simul-Frac"), in addition to several other changes to our customers' job designs, we believe that our available capacity could decline if we decide to reconfigure our fleets to increase active HHP and backup HHP at the wellsites. In addition, in September 2021 and August 2022, we committed to additional conversions of our Tier II equipment to Tier IV DGB, and purchase of new Tier IV DGB. As such, we entered into a conversion and purchase arrangements with our equipment manufacturers for a total of 187,500 HHP of Tier IV DGB equipment and during the period ended June 30, 2022, we received 107,500 HHP of the converted Tier IV DGB equipment and expect to receive the remaining 80,000 HHP at different times through the second half of 2022.

In 2019, we entered into a purchase commitment for DuraStim® electric powered hydraulic fracturing equipment. Given current market conditions, continued supply chain disruptions, inflation, and other factors impacting further development of DuraStim® technology, we do not currently anticipate deploying our DuraStim® equipment in its current form, and accordingly, we evaluated our DuraStim® equipment in its current form for potential impairment. During the second quarter 2022, we determined that certain DuraStim® equipment is impaired and recorded approximately $57.5 million of impairment expense in our pressure pumping reportable segment. The carrying value of our DuraStim® hydraulic fracturing pumps prior to the impairment expense was approximately $68.8 million. The Company could deploy certain other ancillary DuraStim® assets such as, the blenders, datavans, trailers and tractors to alternative uses, and therefore such assets were not included in our impairment analysis. As of June 30, 2022, the carrying value of the ancillary DuraStim® assets that could be deployed to alternative uses was $18.0 million.

Our competitors include many large and small oilfield services companies, including Halliburton Company, Liberty Energy Inc., ProFrac Holding Corp., Nextier Oilfield Solutions Inc., Patterson-UTI Energy Inc., RPC, Inc., and a number of private and locally-oriented businesses. The markets in which we operate are highly competitive. To be successful, an oilfield services company must provide services that meet the specific needs of oil and natural gas E&P companies at competitive prices. Competitive factors impacting sales of our services are price, reputation, technical expertise, emissions profile, service and equipment design and quality, and health and safety standards. Although we believe our customers consider all of these factors, we believe price is a key factor in an E&P company's criteria in choosing a service provider. However, we have recently observed the energy industry and our customers shift to lower emissions equipment, which we believe will be an increasingly important factor in an E&P company's selection of a service provider. The transition to lower emissions equipment has been challenging for companies in the service industry because of the significant capital investment required for next

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generation equipment and the current pricing environment with the service industry, which remains in recovery phase. While we seek to price our services competitively, we believe many of our customers elect to work with us based on our operational efficiencies, productivity, equipment quality, reliability, ability to manage multifaceted logistics challenges, commitment to safety and the ability of our people to handle the most complex Permian Basin well completions.

Our substantial market presence in the Permian Basin positions us well to capitalize on drilling and completion activity in the region. Primarily, our operational focus has been in the Permian Basin's Midland sub-basin, where our customers have operated. However, we have recently increased our operations in the Delaware sub-basin and are well-positioned to support further increases to our activity in this area in response to demand from our customers. Over time, we expect the Permian Basin's Midland and Delaware sub-basins to continue to command a disproportionate share of future North American E&P spending.

Through our pressure pumping segment (which also includes our cementing operations), we primarily provide hydraulic fracturing services to E&P companies in the Permian Basin. Our hydraulic fracturing fleet has been designed to handle the operating conditions commonly experienced in the Permian Basin and the region's increasingly high-intensity well completions (including Simul-Frac, which involves fracturing multiple wellbores at the same time), which are characterized by longer horizontal wellbores, more stages per lateral and increasing amounts of proppant per well.

In addition to our core pressure pumping segment operations, which includes our cementing operations, we also offer coiled tubing services. Through our coiled tubing services segment, we seek to create operational efficiencies for our customers, which could allow us to capture a greater portion of their capital spending across the lifecycle of a well.

Commodity Price and Other Economic Conditions

The oil and gas industry has traditionally been volatile and is influenced by a combination of long-term, short-term and cyclical trends, including domestic and international supply and demand for oil and gas, current and expected future prices for oil and gas and the perceived stability and sustainability of those prices, and capital investments of E&P companies toward their development and production of oil and gas reserves. The oil and gas industry is also impacted by general domestic and international economic conditions such as global supply chain disruptions and inflation, war and political instability in oil producing countries, government regulations (both in the United States and internationally), levels of consumer demand, adverse weather conditions, and other factors that are beyond our control.

In February 2022, Russia launched a large-scale invasion of Ukraine that has led to significant armed hostilities. As a result, the United States, the United Kingdom, the member states of the European Union and other public and private actors have levied severe sanctions on Russian financial institutions, businesses and individuals. This conflict, and the resulting sanctions, has contributed to significant increases and volatility in the prices for oil and natural gas. The geopolitical and macroeconomic consequences of this invasion and associated sanctions remain uncertain, and such events, or any further hostilities in Ukraine or elsewhere, could severely impact the world economy and the oil and gas industry and may adversely affect our financial condition.

The global public health crisis associated with the COVID-19 pandemic also has had an adverse effect on global economic activity and the oil and gas industry. Some of the challenges resulting from the COVID-19 pandemic that have impacted our business include restrictions on movement of personnel and associated gatherings, shortage of skilled labor, cost inflation and supply chain disruptions. In light of the COVID-19 pandemic, most companies, including our customers in the Permian Basin, reacted by closely managing their operating budget and exercising capital discipline. In addition, OPEC+ has indicated that they will continue with their plans to manage production levels by gradually increasing crude oil output.

The Russia-Ukraine war, and the adverse impacts of the COVID-19 pandemic in recent years, have resulted in volatility in supply and demand dynamics for crude oil and associated volatility in crude oil pricing. In 2022, global average crude oil prices have exceeded $100 per barrel, which is the highest prices have been in the last ten years. We believe that the recent surge in global crude oil prices is partly due to the lack of reinvestment in the oil and gas industry in the last two years, and increased demand for oil and gas products, coupled with adverse impact of the Russia-Ukraine war, which has led to various sanctions in Russian crude oil supply and businesses. With the significant increase in global crude oil prices, including WTI crude oil prices, there has been an increase in the Permian Basin rig count from approximately 179 at the beginning of 2021 to approximately 349 at the end of June 2022, according to Baker Hughes. Following the increase in rig count and WTI crude oil price, the oilfield service industry has experienced increased demand for its pressure pumping services, and improved pricing. As a result of the growing demand for pressure pumping services and significant cost inflation across the industry, we negotiated pricing increases with certain of our customers for our pressure pumping services, depending on job design. Although we are currently operating in an improved pricing environment, the rapid increase in cost inflation and supply chain tightness could adversely impact our future profitability, if we are unable to timely pass-through the cost increases to our customers.

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Government regulations and investors are demanding the oil and gas industry transition to a lower emissions operating environment, including the upstream and oilfield service companies. As a result, we are working with our customers and equipment manufacturers to transition to a lower emissions profile. Currently, a number of lower emission solutions for pumping equipment, including Tier IV DGB, electric, direct drive gas turbine and other technologies have been developed, and we expect additional lower emission solutions will be developed in the future. We are continually evaluating these technologies and other investment and acquisition opportunities that would support our existing and new customer relationships. The transition to lower emissions equipment is quickly evolving and will be capital intensive. Over time, we may be required to convert substantially all of our conventional Tier II equipment to lower emissions equipment. If we are unable to quickly transition to lower emissions equipment and meet our and our customers’ emissions goals, the demand for our services could be adversely impacted.

The Permian Basin rig count increase, WTI crude oil price increase and costs inflation could be indicative of an energy market recovery. If the rig count and market conditions continue to improve, including improved customers' pricing and labor availability, and we are able to meet our customers' lower emissions equipment demands, we believe our operational and financial results will also continue to improve. However, if market conditions do not improve, and we are unable to increase our pricing or pass-through future cost increases to our customers, there could be a material adverse impact on our business, results of operations and cash flows.

Our results of operations have historically reflected seasonal tendencies, typically in the fourth quarter, relating to the holiday season, inclement winter weather and exhaustion of our customers' annual budgets. As a result, we typically experience declines in our operating and financial results in November and December, even in a stable commodity price and operations environment.

How We Evaluate Our Operations

Our management uses Adjusted EBITDA or Adjusted EBITDA margin to evaluate and analyze the performance of our various operating segments.

Adjusted EBITDA and Adjusted EBITDA Margin

We view Adjusted EBITDA and Adjusted EBITDA margin as important indicators of performance. We define EBITDA as our earnings, before (i) interest expense, (ii) income taxes and (iii) depreciation and amortization. We define Adjusted EBITDA as EBITDA, plus (i) loss/(gain) on disposal of assets, (ii) stock-based compensation, and (iii) other unusual or nonrecurring (income)/expenses, such as impairment charges, severance, costs related to asset acquisitions, insurance recoveries and one-time professional fees on legal settlements. Adjusted EBITDA margin reflects our Adjusted EBITDA as a percentage of our revenues.

Adjusted EBITDA and Adjusted EBITDA margin are supplemental measures utilized by our management and other users of our financial statements such as investors, commercial banks, and research analysts, to assess our financial performance because it allows us and other users to compare our operating performance on a consistent basis across periods by removing the effects of our capital structure (such as varying levels of interest expense), asset base (such as depreciation and amortization), nonrecurring (income)/expenses and items outside the control of our management team (such as income taxes). Adjusted EBITDA and Adjusted EBITDA margin have limitations as analytical tools and should not be considered as an alternative to net income/(loss), operating income/(loss), cash flow from operating activities or any other measure of financial performance presented in accordance with GAAP.

Note Regarding Non-GAAP Financial Measures

Adjusted EBITDA and Adjusted EBITDA margin are not financial measures presented in accordance with GAAP ("non-GAAP"), except when specifically required to be disclosed by GAAP in the financial statements. We believe that the presentation of Adjusted EBITDA and Adjusted EBITDA margin provide useful information to investors in assessing our financial condition and results of operations because it allows them to compare our operating performance on a consistent basis across periods by removing the effects of our capital structure, asset base, nonrecurring expenses (income) and items outside the control of the Company. Net income (loss) is the GAAP measure most directly comparable to Adjusted EBITDA. Adjusted EBITDA and Adjusted EBITDA margin should not be considered as alternatives to the most directly comparable GAAP financial measure. Each of these non-GAAP financial measures has important limitations as analytical tools because they exclude some, but not all, items that affect the most directly comparable GAAP financial measures. You should not consider Adjusted EBITDA or Adjusted EBITDA margin in isolation or as a substitute for an analysis of our results as reported under GAAP. Because Adjusted EBITDA and Adjusted EBITDA margin may be defined differently by other companies in our industry, our definitions of these non-GAAP financial measures may not be comparable to similarly titled measures of other companies, thereby diminishing their utility.

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Reconciliation of net income (loss) to Adjusted EBITDA (in thousands):


	Three Months Ended June 30, 2022
	Pressure Pumping		All Other		Total
Net income (loss)	$	(24,392)	$	(8,468)	$	(32,860)
Depreciation and amortization	30,528		934		31,462
Impairment expense	57,454		—		57,454
Interest expense	—		669		669
Income tax benefit	—		(8,069)		(8,069)
Loss (gain) on disposal of assets	22,680		(195)		22,485
Stock-based compensation	—		3,458		3,458
Other income	—		(6)		(6)
Other general and administrative expense(1)	21		1,333		1,354
Adjusted EBITDA	$	86,291	$	(10,344)	$	75,947

	Three Months Ended June 30, 2021
	Pressure Pumping		All Other		Total
Net income (loss)	$	(809)	$	(7,702)	$	(8,511)
Depreciation and amortization	32,256		987		33,243
Interest expense	—		159		159
Income tax benefit	—		(3,697)		(3,697)
Loss (gain) on disposal of assets	15,379		(354)		15,025
Stock-based compensation	—		2,909		2,909
Other expense	—		302		302
Other general and administrative expense, (net)(1)	—		(3,737)		(3,737)
Adjusted EBITDA	$	46,826	$	(11,133)	$	35,693

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	Six Months Ended June 30, 2022
	Pressure Pumping		All Other		Total
Net income (loss)	$	4,977	$	(26,020)	$	(21,043)
Depreciation and amortization	61,459		1,858		63,317
Impairment expense	57,454		—		57,454
Interest expense	—		803		803
Income tax benefit	—		(3,932)		(3,932)
Loss (gain) on disposal of assets	39,101		(498)		38,603
Stock-based compensation	—		14,822		14,822
Other income(2)	—		(10,364)		(10,364)
Other general and administrative expense (1)	294		2,526		2,820
Adjusted EBITDA	$	163,285	$	(20,805)	$	142,480

	Six Months Ended June 30, 2021
	Pressure Pumping		All Other		Total
Net income (loss)	$	(14,484)	$	(14,402)	$	(28,886)
Depreciation and amortization	64,770		1,951		66,721
Interest expense	—		335		335
Income tax benefit	—		(10,360)		(10,360)
Loss (gain) on disposal of assets	28,411		(335)		28,076
Stock-based compensation	—		5,396		5,396
Other income	—		(1,487)		(1,487)
Other general and administrative expense (1)	—		(4,698)		(4,698)
Retention bonus and severance expense	—		612		612
Adjusted EBITDA	$	78,697	$	(22,988)	$	55,709

(2)Includes $10.7 million of net tax refund (net of advisory fees) received from the Texas Comptroller of Public Accounts in connection with limited sales, excise, and use tax beginning July 1, 2015 through December 31, 2018.

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Results of Operations

We conducted our business through three operating segments: hydraulic fracturing, cementing and coiled tubing. For reporting purposes, the hydraulic fracturing and cementing operating segments are aggregated into our one reportable segment—pressure pumping. The coiled tubing operating segment and corporate administrative expenses (inclusive of our total income tax expense (benefit), other (income) and expense and interest expense) are included in the "all other" category. Total corporate administrative expense for the three and six months ended June 30, 2022 was $7.7 million and $25.0 million, respectively. Total corporate administrative expense for the three and six months ended June 30, 2021 was $6.5 million and $11.6 million, respectively.

The following table sets forth the results of operations for the periods presented:


(in thousands, except for percentages)	Three Months Ended June 30,						Change Increase (Decrease)
	2022			2021			$			%
Revenue	$	315,083		$	216,887		$	98,196		45.3	%
Less (Add):
Cost of services (1)	218,813			162,837			55,976			34.4	%
General and administrative expense (2)	25,135			17,529			7,606			43.4	%
Depreciation and amortization	31,462			33,243			(1,781)			(5.4)	%
Impairment expense	57,454			—			57,454			100.0	%
Loss on disposal of assets	22,485			15,025			7,460			49.7	%
Interest expense	669			159			510			320.8	%
Other expense (income)	(6)			302			308			102.0	%
Income tax benefit	(8,069)			(3,697)			4,372			118.3	%
Net loss	$	(32,860)		$	(8,511)		$	24,349		286.1	%

Adjusted EBITDA (3)	$	75,947		$	35,693		$	40,254		112.8	%
Adjusted EBITDA Margin (3)	24.1		%	16.5		%	7.6		%	46.1	%

Pressure pumping segment results of operations:
Revenue	$	309,445		$	213,461		$	95,984		45.0	%
Cost of services	$	213,622		$	159,490		$	54,132		33.9	%
Adjusted EBITDA (3)	$	86,291		$	46,826		$	39,465		84.3	%
Adjusted EBITDA Margin (4)	27.9		%	21.9		%	6.0		%	27.4	%

(1)Exclusive of depreciation and amortization.

(2)Inclusive of stock-based compensation.

(3)For definitions of the non-GAAP financial measures of Adjusted EBITDA and Adjusted EBITDA margin and reconciliation of Adjusted EBITDA to our most directly comparable financial measures calculated in accordance with GAAP, please read "How We Evaluate Our Operations". Included in our Adjusted EBITDA is reservation and idle fees of $6.8 million and $1.0 million for the three months ended June 30, 2022 and 2021, respectively.

(4)The non-GAAP financial measure of Adjusted EBITDA margin for the pressure pumping segment is calculated by taking Adjusted EBITDA for the pressure pumping segment as a percentage of our revenue for the pressure pumping segment.

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Three Months Ended June 30, 2022 Compared to the Three Months Ended June 30, 2021

Revenues. Revenues increased 45.3%, or $98.2 million, to $315.1 million during the three months ended June 30, 2022, as compared to $216.9 million during the three months ended June 30, 2021. Our pressure pumping segment revenues increased 45.0%, or $96.0 million, for the three months ended June 30, 2022, as compared to the three months ended June 30, 2021. The increases were primarily attributable to the significant increase in our existing and new customers' activity levels, resulting in higher demand for pressure pumping services and improved pricing. As a result of our customers' increased activity levels, our effectively utilized fleet count rose to approximately 14.8 active fleets during the three months ended June 30, 2022, from approximately 13.1 active fleets for the three months ended June 30, 2021. Included in our revenue for the three months ended June 30, 2022 and 2021 was revenue generated from reservation and idle fees charged to our customer of approximately $6.8 million and $1.0 million, respectively.

Revenues from services other than pressure pumping increased 64.6%, or $2.2 million, to $5.6 million for the three months ended June 30, 2022, as compared to $3.4 million for the three months ended June 30, 2021. The increase in revenue from services other than pressure pumping was primarily attributable to improved pricing and the increase in utilization experienced by our coiled tubing operations, which was driven by increased E&P completions activity.

Cost of Services. Cost of services increased 34.4%, or $56.0 million, to $218.8 million for the three months ended June 30, 2022, as compared to $162.8 million during the three months ended June 30, 2021. Cost of services in our pressure pumping segment increased $54.1 million for the three months ended June 30, 2022, as compared to the three months ended June 30, 2021. These increases were primarily attributable to the significantly increased activity levels resulting from the increased demand for our services and the impact of general cost inflation. As a percentage of pressure pumping segment revenues (including reservation and idle fees), pressure pumping cost of services was 69.0% for the three months ended June 30, 2022, as compared to 74.7% for the three months ended June 30, 2021. Excluding reservation and idle fees revenue of $6.8 million and $1.0 million recorded during the three months ended June 30, 2022 and 2021, respectively, our pressure pumping cost of services as a percentage of pressure pumping revenues decreased to 70.6% during the three months ended June 30, 2022, as compared to 75.1% for the three months ended June 30, 2021. The decrease in the percentages was a result of increased operational efficiencies, reduction in operational downtime and improved pricing across our customer base.

General and Administrative Expenses. General and administrative expenses increased 43.4%, or $7.6 million, to $25.1 million for the three months ended June 30, 2022, as compared to $17.5 million for the three months ended June 30, 2021. The net increase was primarily attributable to an increase during 2022 in (i) non-recurring legal fees, incurred in connection with pending litigation, of approximately $5.1 million, which was primarily as a result of actual expenses incurred in 2022 compared to net insurance recoveries related to nonrecurring professional fees paid to external consultants in connection with the Company's SEC investigation and shareholder litigation in 2021, (ii) consulting and professional fees of approximately $1.3 million, (iii) property and casualty insurance of approximately $0.8 million, (iv) stock-based compensation of approximately $0.5 and (v) property taxes of approximately $0.5 million, which was partially offset by a net decrease of approximately $0.6 million in other general administrative expenses.

Depreciation and Amortization. Depreciation and amortization decreased 5.4%, or $1.8 million, to $31.5 million for the three months ended June 30, 2022, as compared to $33.2 million for the three months ended June 30, 2021. The decrease was primarily attributable to the decrease in our fixed asset base, partly attributable to the disposal of certain fixed assets during the period.

Impairment Expense. During the three months ended June 30, 2022, we recorded $57.5 million in connection with the impairment of our DuraStim® assets. There was no impairment expense during the three months ended June 30, 2021.

Loss on Disposal of Assets. Loss on the disposal of assets increased 49.7%, or $7.5 million, to $22.5 million for the three months ended June 30, 2022, as compared to $15.0 million for the three months ended June 30, 2021. The increase was primarily attributable to the significant increase in our utilization levels, resulting in an increase in the operational intensity on our pressure pumping equipment. Upon sale or retirement of property and equipment, including replaced fluid and power ends, the cost and related accumulated depreciation of such assets or components are removed from the balance sheet and the net amount is recognized as loss on disposal of assets.

Interest Expense. There was no significant change in interest expense. Interest expense slightly increased to approximately $0.7 million for the three months ended June 30, 2022, as compared to $0.2 million for the three months ended June 30, 2021. The increase was primarily attributable to the partial write down of unamortized capitalized loan origination cost in connection with the modification to our credit facility.

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Income Taxes. For the three months ended June 30, 2022, the Company has utilized the discrete effective tax rate method as allowed by Accounting Standards Codification (“ASC”) 740-270-30-18, Income Taxes - Interim Reporting to calculate its interim tax provision. The discrete method treats the year-to-date period as if it was the annual period and determines the income tax expense or benefit on that basis. The Company believes that, at this time, the use of this discrete method is more appropriate than the annual effective tax rate method as the annual effective tax rate is not reliable because small changes in estimated “ordinary” income would result in significant changes in the estimated annual effective tax rate. Total income tax benefit was $8.1 million resulting in an effective tax rate of 19.7% for the three months ended June 30, 2022, as compared to income tax benefit of $3.7 million or an effective tax rate of 30.3% for the three months ended June 30, 2021. The change in income tax benefit recorded during the three months ended June 30, 2022, compared to the three months ended June 30, 2021, is primarily attributable to the difference in the estimated pre-tax loss in 2022, as compared to 2021.

The following table sets forth the results of operations for the periods presented:


(in thousands, except for percentages)	Six Months Ended June 30,						Change Increase (Decrease)
	2022			2021			$			%
Revenue	$	597,763		$	378,345		$	219,418		58.0	%
Less (Add):
Cost of services (1)	416,083			286,215			129,868			45.4	%
General and administrative expense (2)	56,842			37,731			19,111			50.7	%
Depreciation and amortization	63,317			66,721			(3,404)			(5.1)	%
Impairment expense	57,454			—			57,454			100.0	%
Loss on disposal of assets	38,603			28,076			10,527			37.5	%
Interest expense	803			335			468			139.7	%
Other income	(10,364)			(1,487)			8,877			597.0	%
Income tax benefit	(3,932)			(10,360)			(6,428)			(62.0)	%
Net loss	$	(21,043)		$	(28,886)		$	(7,843)		(27.2)	%

Adjusted EBITDA (3)	$	142,480		$	55,709		$	86,771		155.8	%
Adjusted EBITDA Margin (3)	23.8		%	14.7		%	9.1		%	61.9	%

Pressure pumping segment results of operations:
Revenue	$	586,557		$	371,652		$	214,905		57.8	%
Cost of services	$	406,255		$	279,258		$	126,998		45.5	%
Adjusted EBITDA (3)	$	163,285		$	78,697		$	84,588		107.5	%
Adjusted EBITDA Margin (4)	27.8		%	21.2		%	6.6		%	31.1	%

(1)Exclusive of depreciation and amortization.

(2)Inclusive of stock-based compensation.

(3)For definitions of the non-GAAP financial measures of Adjusted EBITDA and Adjusted EBITDA margin and reconciliation of Adjusted EBITDA to our most directly comparable financial measures calculated in accordance with GAAP, please read "How We Evaluate Our Operations". Included in our Adjusted EBITDA is reservation and idle fees of $13.5 million and $5.3 million for the six months ended June 30, 2022 and 2021, respectively.

Six Months Ended June 30, 2022 Compared to the Six Months Ended June 30, 2021

Revenues. Revenues increased 58.0%, or $219.4 million, to $597.8 million during the six months ended June 30, 2022, as compared to $378.3 million during the six months ended June 30, 2021. Our pressure pumping segment revenues increased 57.8%, or $214.9 million, for the six months ended June 30, 2022, as compared to the six months ended June 30, 2021. The increases were primarily attributable to the significant increase in our existing and new customers' activity levels, resulting in higher demand for pressure pumping services and improved pricing. As a result of our customers' increased activity levels, our effectively utilized fleet count rose to approximately 14.3 active fleets during the six months ended June 30, 2022, from approximately 11.7 active fleets for the six months ended June 30, 2021. Included in our revenue for the six months ended

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June 30, 2022 and 2021 was revenue generated from reservation and idle fees charged to our customer of approximately $13.5 million and $5.3 million, respectively.

Revenues from services other than pressure pumping increased 67.4%, or $4.5 million, to $11.2 million for the six months ended June 30, 2022, as compared to $6.7 million for the six months ended June 30, 2021. The increase in revenue from services other than pressure pumping was primarily attributable to improved pricing and the increase in utilization experienced by our coiled tubing operations, which was driven by increased E&P completions activity.

Cost of Services. Cost of services increased 45.4%, or $129.9 million, to $416.1 million for the six months ended June 30, 2022, as compared to $286.2 million during the six months ended June 30, 2021. Cost of services in our pressure pumping segment increased $127.0 million for the six months ended June 30, 2022, as compared to the six months ended June 30, 2021. These increases were primarily attributable to the significantly increased activity levels and general cost inflation. As a percentage of pressure pumping segment revenues (including reservation and idle fees), pressure pumping cost of services was 69.3% for the six months ended June 30, 2022, as compared to 75.1% for the six months ended June 30, 2021. Excluding reservation and idle fees revenue of $13.5 million and $5.3 million recorded during the six months ended June 30, 2022 and 2021, respectively, our pressure pumping cost of services as a percentage of pressure pumping revenues decreased to 70.9% during the six months ended June 30, 2022, as compared to 76.2% for the six months ended June 30, 2021. The decrease in the percentages was a result of increased operational efficiencies, reduction in operational downtime and improved pricing across our customer base.

General and Administrative Expenses. General and administrative expenses increased 50.7%, or $19.1 million, to $56.8 million for the six months ended June 30, 2022, as compared to $37.7 million for the six months ended June 30, 2021. The net increase was primarily attributable to an increase during 2022 in (i) stock-based compensation expense of $9.4 million, which was primarily attributable to the non-recurring incremental stock-based compensation associated with the acceleration of stock awards upon resignation of a former executive, (ii) non-recurring legal fees, incurred in connection with pending litigation, of approximately $7.5 million, which was primarily as a result of actual expenses of approximately $2.8 million incurred in 2022 compared to net insurance recoveries of approximately $4.7 million related to nonrecurring professional fees paid to external consultants in connection with the Company's SEC investigation, shareholder litigation and other legal matters in 2021, and (iii) consulting and professional fees of approximately $2.3 million, which was partially offset by a net decrease of approximately $0.1 million in other general administrative expenses.

Depreciation and Amortization. Depreciation and amortization decreased 5.1%, or $3.4 million, to $63.3 million for the six months ended June 30, 2022, as compared to $66.7 million for the six months ended June 30, 2021. The decrease was primarily attributable to the decrease in our fixed asset base, partly attributable to the disposal of certain fixed assets during the period.

Impairment Expense. During the six months ended June 30, 2022, we recorded $57.5 million in connection with the impairment of our DuraStim® assets. There was no impairment expense during the six months ended June 30, 2021.

Loss on Disposal of Assets. Loss on the disposal of assets increased 37.5%, or $10.5 million, to $38.6 million for the six months ended June 30, 2022, as compared to $28.1 million for the six months ended June 30, 2021. The increase was primarily attributable to the significant increase in our utilization levels, resulting in an increase in the operational intensity on our pressure pumping equipment. Upon sale or retirement of property and equipment, including replaced fluid and power ends, the cost and related accumulated depreciation of such assets or components are removed from the balance sheet and the net amount is recognized as loss on disposal of assets.

Interest Expense. There was no significant change in interest expense. Interest expense slightly increased to $0.8 million for the six months ended June 30, 2022, as compared to $0.3 million for the six months ended June 30, 2021. The increase was primarily attributable to the partial write down of unamortized capitalized loan origination cost in connection with the modification to our credit facility.

Other Income. Other income increased 597.0%, or $8.9 million, to $10.4 million for the six months ended June 30, 2022, as compared to $1.5 million for the six months ended June 30, 2021. The increase was primarily attributable to the net refund to the Company of $10.7 million from sales, excise and use taxes and partially offset by other expense relating to our lender's commitment fees.

Income Taxes. For the six months ended June 30, 2022, the Company has utilized the discrete effective tax rate method as allowed by ASC 740-270-30-18, Income Taxes - Interim Reporting to calculate its interim tax provision. The discrete method treats the year-to-date period as if it was the annual period and determines the income tax expense or benefit on that basis. The Company believes that, at this time, the use of this discrete method is more appropriate than the annual effective tax rate method as the annual effective tax rate is not reliable because small changes in estimated “ordinary” income would result in

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significant changes in the estimated annual effective tax rate. Total income tax benefit was approximately $3.9 million resulting in an effective tax rate of 15.7% for the six months ended June 30, 2022, as compared to income tax benefit of $10.4 million or an effective tax rate of 26.4% for the six months ended June 30, 2021. The change in income tax benefit recorded during the six months ended June 30, 2022, compared to that during the six months ended June 30, 2021, is primarily attributable to the difference in the estimated pre-tax loss in 2022, as compared to 2021. Furthermore, the change in the effective tax rate of 15.7% from 26.4% was due to nondeductible expenses and discrete items such as stock compensation expense recorded during the six months ended June 30, 2021

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Liquidity and Capital Resources

Our liquidity is currently provided by (i) existing cash balances, (ii) operating cash flows and (iii) borrowings under our ABL Credit Facility (as defined below). Our cash is primarily used to fund our operations, support growth opportunities and satisfy future debt payments, if any. Our Borrowing Base (as defined below), as redetermined monthly, is tied to 85.0% to 90% of eligible accounts receivable. Changes to our operational activity levels and our customers' credit ratings have an impact on our total eligible accounts receivable, which could result in significant changes to our Borrowing Base and therefore our availability under our ABL Credit Facility.

As of June 30, 2022, we had no borrowings under our ABL Credit Facility, and our total liquidity was approximately $185.3 million, consisting of cash and cash equivalents of $69.8 million and $115.5 million of availability under our ABL Credit Facility.

In 2020, when demand for our services was significantly depressed following the rapidly rising health crisis associated with the COVID-19 pandemic and the energy industry disruptions, the Company experienced a significant decrease in its liquidity. However, with the gradual recovery in the energy industry, improvements in our pricing and an increase in demand for our services, our liquidity position has gradually improved, although we expect our overall liquidity to decline during 2022 as we make additional capital investments. Moreover, the current market conditions resulting from the COVID-19 pandemic have and may in the future change rapidly and there could be a new outbreak of a COVID-19 variant that could result in travel restrictions, business closures and institution of quarantining and/or other activity restrictions, which could negatively impact our future operations, revenue, profitability and cash flows if not contained or if the vaccines currently distributed and administered to people are not as effective as anticipated in curbing the spread of any such new COVID-19 variant.

The industry transition to lower emissions pressure pumping equipment could require us to make significant investment in DGB or electric solutions in order to continue to meet our current and future customers' equipment demand. If we are unable to timely reinvest in lower emissions equipment, the future demand for our pressure pumping services may be adversely impacted, which could negatively impact our future operations, revenue, profitability and cash flows.

There can be no assurance that our operations and other capital resources will provide cash in sufficient amounts to maintain planned or future levels of capital expenditures. Future cash flows are subject to a number of variables, and are highly dependent on the drilling, completion, and production activity by our customers, which in turn is highly dependent on oil and natural gas prices. Depending upon market conditions and other factors, we may issue equity and debt securities or take other actions necessary to fund our business or meet our future long-term liquidity requirements.

Our revolving credit facility, as amended in 2018, had a total borrowing capacity of $300.0 million (subject to the borrowing base limit), with a maturity date of December 19, 2023. The revolving credit facility had a borrowing base of 85% of monthly eligible accounts receivable less customary reserves, as redetermined monthly. The revolving credit facility included a springing fixed charge coverage ratio to apply when excess availability was less than the greater of (i) 10% of the lesser of the facility size or the borrowing base or (ii) $22.5 million. Borrowings under the revolving credit facility accrued interest based on a three-tier pricing grid tied to availability, and we had the option to elect for loans to be based on either LIBOR or base rate, plus the applicable margin, which ranged from 1.75% to 2.25% for LIBOR loans and 0.75% to 1.25% for base rate loans, with a LIBOR floor of zero.

Effective April 13, 2022, the Company entered into an amendment and restatement of its revolving credit facility (as amended and restated, "ABL Credit Facility"). The ABL Credit Facility decreased the borrowing capacity to $150.0 million (subject to the Borrowing Base limit), with a maturity date extended to April 13, 2027. The ABL Credit Facility has a borrowing base of 85% to 90%, depending on the credit ratings of our accounts receivable counterparties, of monthly eligible accounts receivable less customary reserves (the "Borrowing Base"), as redetermined monthly. The Borrowing Base as of June 30, 2022, was approximately $120.5 million. The ABL Credit Facility includes a springing fixed charge coverage ratio to apply when excess availability is less than the greater of (i) 10% of the lesser of the facility size or the Borrowing Base or (ii) $10.0 million. Under this facility we are required to comply, subject to certain exceptions and materiality qualifiers, with certain customary affirmative and negative covenants, including, but not limited to, covenants pertaining to our ability to incur liens, indebtedness, changes in the nature of our business, mergers and other fundamental changes, disposal of assets, investments and restricted payments, amendments to our organizational documents or accounting policies, prepayments of certain debt, dividends, transactions with affiliates, and certain other activities. Borrowings under the ABL Credit Facility are secured by a first priority lien and security interest in substantially all assets of the Company. Borrowings under the ABL Credit Facility accrue interest based on a three-tier pricing grid tied to availability, and we may elect for loans to be based on either the Secured Overnight Financing Rate ("SOFR") or the base rate, plus the applicable margin, which ranges from 1.50% to 2.00% for SOFR loans and 0.50% to 1.00% for base rate loans.

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Future Sources and Use of Cash and Contractual Obligations

Capital expenditures incurred were $89.1 million during the three months ended June 30, 2022, as compared to $30.8 million during the three months ended June 30, 2021. The significant portion of our total capital expenditures incurred were comprised of primarily maintenance and DGB conversion capital expenditures.

Our future material use of cash will be to fund our capital expenditures. Capital expenditures for 2022 are projected to be primarily related to maintenance capital expenditures to support our existing pressure pumping assets, costs to convert some existing equipment to lower emissions pressure pumping equipment, strategic purchases and other ancillary equipment purchases, subject to market conditions and customer demand. Our future capital expenditures depend on our projected operational activity, emission requirements and planned conversions to lower emissions equipment, among other factors, which could vary significantly throughout the year. We could incur significant additional capital expenditures if our projected activity levels increase during the course of the year, inflation and supply chain tightness continue to adversely impact our operations or we invest in new or different lower emissions equipment. The Company will continue to evaluate the emissions profile of its fleet over the coming years and may, depending on market conditions, convert or retire additional conventional Tier II equipment in favor of lower emissions equipment. The Company’s decisions regarding the retirement or conversion of equipment or the addition of lower emissions equipment will be subject to a number of factors, including (among other factors) the availability of equipment, including parts and major components, supply chain disruptions, prevailing and expected commodity prices, customer demand and requirements and the Company’s evaluation of projected returns on conversion or other capital expenditures. Depending on the impacts of these factors, the Company may decide to retain conventional equipment for a longer period of time or accelerate the retirement, replacement or conversion of that equipment.

We anticipate our capital expenditures will be funded by existing cash, cash flows from operations, and if needed, borrowings under our ABL Credit Facility. Our cash flows from operations will be generated from services we provide to our customers.

In the normal course of business, we enter into various contractual obligations and incur expenses in connection with routine growth, conversion and maintenance capital expenditures that impact our future liquidity. There were no other known future material contractual obligations as of June 30, 2022. In August 2022, we entered into a contractual arrangement with our equipment manufacturer to purchase and convert additional Tier IV DGB equipment, with total cost of approximately $43.0 million.

Cash and Cash Flows

The following table sets forth the historical cash flows for the six months ended June 30, 2022, and 2021:


	Six Months Ended June 30,
(in thousands)	2022		2021

Net cash provided by operating activities	$	103,308	$	61,480
Net cash used in investing activities	$	(141,568)	$	(50,920)
Net cash used in financing activities	$	(3,869)	$	(6,631)

Cash Flows From Operating Activities

Net cash provided by operating activities was $103.3 million for the six months ended June 30, 2022, compared to $61.5 million for the six months ended June 30, 2021. The net increase of approximately $41.8 million was primarily due to the increase in our activity levels resulting from the increase in the demand for our services, driven by increased crude oil prices, net tax refund received, and partially offset with the timing of collections of our receivables from customers and payments to vendors.

Cash Flows From Investing Activities

Net cash used in investing activities increased to $141.6 million for the six months ended June 30, 2022, from $50.9 million for the six months ended June 30, 2021. The increase was primarily attributable to our investment in lower emissions Tier IV DGB equipment.

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Cash Flows From Financing Activities

Net cash used in financing activities decreased to $3.9 million for the six months ended June 30, 2022, from $6.6 million for the six months ended June 30, 2021. The net decrease in cash used in financing activities during the six months ended June 30, 2022, was primarily a result of the reduction in the amount of net settlement of equity awards and no repayments of insurance financing in 2022, compared to the six months ended June 30, 2021.

Off-Balance Sheet Arrangements

We had no off-balance sheet arrangements as of June 30, 2022.

Critical Accounting Policies and Estimates

There have been no material changes during the six months ended June 30, 2022 to the methodology applied by our management for critical accounting policies previously disclosed in our Form 10-K. Please refer to Part II, Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies and Estimates" in our Form 10-K for a discussion of our critical accounting policies and estimates.

Recently Issued Accounting Standards

Disclosure concerning recently issued accounting standards is incorporated by reference to Note 2 of our Condensed Consolidated Financial Statements (Unaudited) contained in this Form 10-Q.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As of June 30, 2022, there have been no material changes in market risk from the information provided in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” or “Quantitative and Qualitative Disclosures of Market Risk” in our Form 10-K.

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ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

We maintain disclosure controls and procedures that are designed to provide reasonable assurance that the information required to be disclosed by us in our reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and that such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

As required by Rule 13a-15(b) under the Exchange Act, we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this quarterly report. Based upon that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective at the reasonable assurance level as of June 30, 2022.

Changes in Internal Control over Financial Reporting

There were no changes in our system of internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the quarter ended June 30, 2022 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II – OTHER INFORMATION

ITEM 1. Legal Proceedings

See “Note 10 – Commitments and Contingencies” in the Notes to Condensed Consolidated Financial Statements for further information.

ITEM 1A. Risk Factors

There have been no material changes to the risk factors disclosed in Part I, Item 1A. of our Form 10-K.

ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

ITEM 3. Defaults Upon Senior Securities

None.

ITEM 4. Mine Safety Disclosures

Not applicable.

ITEM 5. Other Information

None.

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ITEM 6. Exhibits

The exhibits required to be filed or furnished by Item 601 of Regulation S-K are listed below.


3.1						Amended and Restated Certificate of Incorporation of ProPetro Holding Corp. dated as of June 19, 2019 (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K, dated June 19, 2019).
3.2						Amended and Restated Bylaws of ProPetro Holding Corp. (incorporated by reference to Exhibit 3.2 to the Company's Current Report on Form 8-K, dated June 19, 2019).
3.3						Certificate of Designations of Series B Junior Participating Preferred Stock of ProPetro Holding Corp. (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K, dated April 14, 2020).
10.1						Restatement Agreement, dated as of April 13, 2022, by and among ProPetro Holding Corp., and ProPetro Services, Inc., Barclays Bank PLC, as the Administrative Agent, the Collateral Agent, a Letter of Credit Issuer and the Swingline Lender, and each of the Lenders and Letter of Credit Issuers from time to time party thereto (incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K, dated April 13, 2022).
31.1*						Certification of Principal Executive Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Exchange Act Rules, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*						Certification of Principal Financial Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Exchange Act Rules, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**						Certification of Principal Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted by Section 906 of the Sarbanes-Oxley Act of 2002.
32.2**						Certification of Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted by Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS*						XBRL Instance Document
101.SCH*						XBRL Taxonomy Extension Schema Document
101.CAL*						XBRL Taxonomy Extension Calculation Linkbase Document
101.LAB*						XBRL Taxonomy Extension Label Linkbase Document
101.PRE*						XBRL Taxonomy Extension Presentation Linkbase Document
101.DEF*						XBRL Taxonomy Extension Definition Linkbase Document
104*						Cover Page Interactive Data File - the cover page interactive data file does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document


*			Filed herewith.
**			Furnished herewith.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

SIGNATURES

Date:

August 4, 2022

By:

/s/ Samuel D. Sledge

Samuel D. Sledge

Chief Executive Officer and Director

(Principal Executive Officer)

By:

/s/ David S. Schorlemer

David S. Schorlemer

Chief Financial Officer

(Principal Financial Officer)

By:

/s/ Elo Omavuezi

Elo Omavuezi

Chief Accounting Officer

(Principal Accounting Officer)

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