August 5, 2021 - 10-Q: Quarterly report pursuant to Section 13 or 15(d)

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, 2021


☐			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 28, 2021, was 103,259,971.

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 J une 30, 202 1 and December 31, 20 20	1
	Condensed Consolidated Statements of Operations for the three and six months ended June 30, 202 1 and 20 20	2
	Condensed Consolidated Statements of Shareholders' Equity for the three and six months ended June 30, 202 1 and 20 20	3
	Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 202 1 and 20 20	4
	Notes to Condensed Consolidated Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	19
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	30
Item 4.	Controls and Procedures	31

PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	32
Item 1A.	Risk Factors	32
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	32
Item 3.	Defaults Upon Senior Securities	32
Item 4.	Mine Safety Disclosures	32
Item 5.	Other Information	32
Item 6.	Exhibits	33
	Signatures	34

-i-

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q (this "Form 10-Q") contains forward-looking statements that are intended to be covered by the safe harbor provided by the Private Securities Litigation Reform Act of 1995. All statements other than statements of historical facts contained in this Form 10-Q are forward-looking statements within the meaning of Section 21E of the Securities and Exchange Act of 1934, as amended (the "Exchange Act"). 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 world health events, including the coronavirus ("COVID-19") pandemic, related economic repercussions and the resulting severe disruption in the oil and gas industry and negative impact on demand for oil and gas, which is negatively impacting our business;

•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;

•uncertainty regarding the timing, pace and extent of an economic recovery in the United States and elsewhere, which in turn will likely affect demand for crude oil and natural gas and therefore the demand for our services;

•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;

•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;

•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;

•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);

•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 the new DuraStim® hydraulic fracturing equipment and associated power solutions;

•operating hazards, natural disasters, weather-related delays, casualty losses and other matters beyond our control;

•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 Shareholder Derivative Lawsuit (each defined herein);

•the timing and outcome of, including potential expense associated with, the pending U.S. Securities and Exchange Commission (the "SEC") investigation;

•the potential impact on our business and stock price of any announcements regarding the SEC's pending investigation, the Logan Lawsuit or the Shareholder Derivative Lawsuit; and

•our ability to successfully execute on our plans and objectives.

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, 2020, 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 effective 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.

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PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)

(Unaudited)


	June 30, 2021		December 31, 2020
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	72,701	$	68,772
Accounts receivable - net of allowance for credit losses of $140 and $1,497, respectively	138,309		84,244
Inventories	2,641		2,729
Prepaid expenses	3,469		11,199
Other current assets	14		782
Total current assets	217,134		167,726
PROPERTY AND EQUIPMENT - net of accumulated depreciation	847,512		880,477
OPERATING LEASE RIGHT-OF-USE ASSETS	562		709
OTHER NONCURRENT ASSETS:
Other noncurrent assets	1,578		1,827
Total other noncurrent assets	1,578		1,827
TOTAL ASSETS	$	1,066,786	$	1,050,739
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	136,364	$	79,153
Operating lease liabilities	351		334
Accrued and other current liabilities	20,062		24,676
Total current liabilities	156,777		104,163
DEFERRED INCOME TAXES	64,980		75,340
NONCURRENT OPERATING LEASE LIABILITIES	286		465
Total liabilities	222,043		179,968
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, 103,227,040 and 100,912,777 shares issued, respectively	103		101
Additional paid-in capital	837,971		835,115
Retained earnings	6,669		35,555
Total shareholders’ equity	844,743		870,771
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	1,066,786	$	1,050,739

See notes to condensed consolidated financial statements.

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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,
	2021		2020		2021		2020
REVENUE - Service revenue	$	216,887	$	106,109	$	378,345	$	501,178
COSTS AND EXPENSES
Cost of services (exclusive of depreciation and amortization)	162,837		68,193		286,215		369,041
General and administrative (inclusive of stock-based compensation)	17,529		20,331		37,731		45,269
Depreciation and amortization	33,243		40,173		66,721		80,377
Impairment expense	—		—		—		16,654
Loss on disposal of assets	15,025		8,734		28,076		28,588
Total costs and expenses	228,634		137,431		418,743		539,929
OPERATING LOSS	(11,747)		(31,322)		(40,398)		(38,751)
OTHER EXPENSE:
Interest expense	(159)		(791)		(335)		(2,072)
Other (expense)/Income	(302)		(267)		1,487		(271)
Total other (expense)/Income	(461)		(1,058)		1,152		(2,343)
LOSS BEFORE INCOME TAXES	(12,208)		(32,380)		(39,246)		(41,094)
INCOME TAX BENEFIT	3,697		6,460		10,360		7,370
NET LOSS	$	(8,511)	$	(25,920)	$	(28,886)	$	(33,724)

NET LOSS PER COMMON SHARE:
Basic	$	(0.08)	$	(0.26)	$	(0.28)	$	(0.33)
Diluted	$	(0.08)	$	(0.26)	$	(0.28)	$	(0.33)

WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic	102,398		100,821		101,976		100,754
Diluted	102,398		100,821		101,976		100,754

See notes to condensed consolidated financial statements.

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PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY

(In thousands)

(Unaudited)


	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 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 loss	—	—		—		(8,511)		(8,511)
BALANCE - June 30, 2021	103,227	$	103	$	837,971	$	6,669	$	844,743


	Six Months Ended June 30, 2020
	Common Stock
	Shares	Amount		Additional Paid-In Capital		Retained Earnings		Total
BALANCE - January 1, 2020	100,624	$	101	$	826,629	$	142,575	969,305
Stock-based compensation cost	—	—		471		—		471
Issuance of equity awards, net	154	—		—		—		—
Tax withholdings paid for net settlement of equity awards	—	—		(456)		—		(456)
Net loss	—	—		—		(7,804)		(7,804)
BALANCE - March 31, 2020	100,778	$	101	$	826,644	$	134,771	$	961,516
Stock-based compensation cost	—	—		2,962		—		2,962
Issuance of equity awards, net	111	—		—		—		—
Tax withholdings paid for net settlement of equity awards	—	—		(129)		—		(129)
Net loss	—	—		—		(25,920)		(25,920)
BALANCE - June 30, 2020	100,889	$	101	$	829,477	$	108,851	$	938,429

See notes to condensed consolidated financial statements.

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PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)


	Six Months Ended June 30,
	2021		2020
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(28,886)	$	(33,724)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization	66,721		80,377
Impairment expense	—		16,654
Deferred income tax benefit	(10,360)		(7,773)
Amortization of deferred debt issuance costs	269		270
Stock-based compensation	5,396		3,433
Provision for credit losses	140		448
Loss on disposal of assets	28,076		28,588
Changes in operating assets and liabilities:
Accounts receivable	(53,762)		146,181
Other current assets	325		1,613
Inventories	89		(369)
Prepaid expenses	7,711		5,833
Accounts payable	44,933		(135,592)
Accrued and other current liabilities	828		(8,635)
Accrued interest	—		(394)
Net cash provided by operating activities	61,480		96,910
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(52,187)		(80,702)
Proceeds from sale of assets	1,267		2,677
Net cash used in investing activities	(50,920)		(78,025)
CASH FLOWS FROM FINANCING ACTIVITIES:
Repayments of borrowings	—		(130,000)
Payment of finance lease obligation	—		(30)
Repayments of insurance financing	(4,093)		—
Proceeds from exercise of equity awards	3,235		—
Tax withholdings paid for net settlement of equity awards	(5,773)		(585)
Net cash used in financing activities	(6,631)		(130,615)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	3,929		(111,730)
CASH AND CASH EQUIVALENTS - Beginning of period	68,772		149,036
CASH AND CASH EQUIVALENTS - End of period	$	72,701	$	37,306

See notes to condensed consolidated financial statements.

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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, 2020 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 daily idle fee charges if a customer were to idle committed hydraulic fracturing equipment. The Company recognizes revenue related to idle fee charges on a daily basis 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, 2021 and December 31, 2020, accrued revenue (unbilled receivable) included as part of our accounts receivable was $14.1 million and $8.6 million, respectively. At June 30, 2021, the transaction price allocated to the remaining performance obligation for our partially

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PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 - Basis of Presentation (Continued)

completed hydraulic fracturing operations was $26.5 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, 2021, the Company had $0.1 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 for the oil and gas industry. We evaluated the historic loss experience on our accounts receivable and also considered separately customers with receivable balances that may 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, 2021:


(in thousands)

Balance - January 1, 2021	$	1,497
Provision for credit losses during the period	140
Write-off during the period	(1,497)
Balance - June 30, 2021	$	140

Note 2 - Recently Issued Accounting Standards

Recently Issued Accounting Standards Adopted in 2021

In December 2019, the Financial Accounting Standards Board (“FASB”) Accounting Standards Update (“ASU”) issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. ASU 2019-12 removes certain exceptions to the general principles in Topic 740 in Generally Accepted Accounting Principles. ASU 2019-12 is effective for public entities for fiscal years beginning after December 15, 2020, with early adoption permitted. Effective January 1, 2021, we adopted this guidance and the adoption did not materially affect the Company’s condensed consolidated financial statements.

Recently Issued Accounting Standards Not Yet Adopted in 2021

In March 2020, the 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. The Company is currently assessing the impact of the LIBOR transition and this ASU on 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:

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PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 3 - Fair Value Measurement (Continued)

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.

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, 2021, and December 31, 2020, approximated or equaled their carrying values as reflected in our condensed consolidated balance sheets.

Assets Measured at Fair Value on a Nonrecurring Basis

In the first quarter of 2020, the negative future near-term outlook resulting from the continued idling of our Permian drilling assets and current market prices were indicative of potential impairment, resulting in the Company comparing the carrying value of the Permian drilling assets with its estimated fair value. In the first quarter of 2020, we determined that the carrying value of the Permian drilling assets was greater than its estimated fair value. Accordingly, impairment expense of $1.1 million was recorded for our Permian drilling assets during the three months ended March 31, 2020. There was no impairment of assets during the six months ended June 30, 2021.

In 2019, the Company entered an agreement with its equipment manufacturer granting the Company the option to purchase additional 108,000 hydraulic horsepower ("HHP") of DuraStim® equipment, with the purchase option expiring at different times through July 31, 2022, as amended. The option fee of $6.1 million, classified as a deposit for property and equipment as part of our pressure pumping reportable segment, was fully impaired and written off in the first quarter of 2020 because it was not probable that the Company will exercise the option to purchase the equipment given the then current depressed crude oil prices and other market conditions that have resulted in a decline in the demand for our hydraulic fracturing services.

The total non-cash property and equipment impairment charges recorded during the six months ended June 30, 2021, and 2020 in our hydraulic fracturing and drilling segments was $0 and $7.2 million, respectively.

We generally apply fair value techniques to our reporting units on a nonrecurring basis associated with valuing potential impairment loss related to goodwill. Our estimate of the reporting unit fair value is based on a combination of income and market approaches, Level 1 and 3, respectively, in the fair value hierarchy. The income approach involves the use of a discounted cash flow method, with the cash flow projections discounted at an appropriate discount rate. The market approach involves the use of comparable public companies' market multiples in estimating the fair value. Significant assumptions include projected revenue growth, capital expenditures, utilization, gross margins, discount rates, terminal growth rates, and weight allocation between income and market approaches. If the reporting unit's carrying amount exceeds its fair value, we consider goodwill impaired, and the impairment loss is calculated and recorded in the period. There were no additions to, or disposals of, goodwill during the six months ended June 30, 2021. In the first quarter of 2020, the depressed crude oil prices and crude oil storage challenges faced in the U.S. oil and gas industry triggered the Company to perform an interim goodwill impairment test, and as a result, we compared the carrying value of the goodwill in our hydraulic fracturing reporting unit with the estimated fair value. Our impairment test also considered other relevant factors, including market capitalization and market participants' view of the oil and gas industry in reaching our conclusion that that carrying value of our goodwill in our pressure pumping reportable segment of $9.4 million was fully impaired during the first quarter of 2020. Accordingly, during the six months ended June 30, 2020, we recorded goodwill impairment of approximately $9.4 million.

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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 ("ABL Credit Facility"), as amended, has a total borrowing capacity of $300 million (subject to the Borrowing Base limit), with a maturity date of December 19, 2023. The ABL Credit Facility has a borrowing base of 85% of monthly eligible accounts receivable less customary reserves (the "Borrowing Base"), as redetermined monthly. The Borrowing Base as of June 30, 2021, was approximately $71.8 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) $22.5 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 LIBOR or base rate, plus the applicable margin, which ranges 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.

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 ABL Credit Facility as of June 30, 2021, and December 31, 2020.

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 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, 2021, was $6.5 million and $11.6 million, respectively. The corporate administrative expense for the three and six months ended June 30, 2020, was $10.6 million and $20.9 million, respectively.

Our hydraulic fracturing operating segment revenue approximated 93.7% and 93.5% of our pressure pumping revenue during the three and six months ended June 30, 2021, respectively. During the three and six months ended June 30, 2020, our hydraulic fracturing operating segment revenue approximated 89.7% and 93.7% of our pressure pumping revenue, respectively.

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

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):

-8-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 5 - Reportable Segment Information (Continued)


	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 at June 30, 2021	$	1,029,140	$	37,646	$	1,066,786

	Three Months Ended June 30, 2020
	Pressure Pumping		All Other		Total
Service revenue	$	103,815	$	2,294	$	106,109
Adjusted EBITDA	$	34,030	$	(8,620)	$	25,410
Depreciation and amortization	$	38,910	$	1,263	$	40,173
Capital expenditures	$	10,034	$	1,846	$	11,880
Total assets at December 31, 2020	$	1,009,631	$	41,108	$	1,050,739


	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 at June 30, 2021	$	1,029,140	$	37,646	$	1,066,786

	Six Months Ended June 30, 2020
	Pressure Pumping		All Other		Total
Service revenue	$	490,735	$	10,443	$	501,178
Adjusted EBITDA	$	112,696	$	(12,362)	$	100,334
Depreciation and amortization	$	77,879	$	2,498	$	80,377
Capital expenditures	$	49,301	$	2,674	$	51,975
Total assets at December 31, 2020	$	1,009,631	$	41,108	$	1,050,739

-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, 2021
	Pressure Pumping		All Other		Total
Net 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(1)	—		(3,737)		(3,737)
Adjusted EBITDA	$	46,826	$	(11,133)	$	35,693

	Three Months Ended June 30, 2020
	Pressure Pumping		All Other		Total
Net loss	$	(13,528)	$	(12,392)	$	(25,920)
Depreciation and amortization	38,910		1,263		40,173
Interest expense	—		791		791
Income tax benefit	—		(6,460)		(6,460)
Loss on disposal of assets	8,587		147		8,734
Stock-based compensation	—		2,962		2,962
Other expense	—		267		267
Other general and administrative expense(1)	—		4,802		4,802
Retention bonus and severance expense	61		—		61
Adjusted EBITDA	$	34,030	$	(8,620)	$	25,410

-10-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 5 - Reportable Segment Information (Continued)


	Six Months Ended June 30, 2021
	Pressure Pumping		All Other		Total
Net 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

	Six Months Ended June 30, 2020
	Pressure Pumping		All Other		Total
Net loss	$	(9,220)	$	(24,504)	$	(33,724)
Depreciation and amortization	77,879		2,498		80,377
Impairment expense	15,559		1,095		16,654
Interest expense	1		2,071		2,072
Income tax benefit	—		(7,370)		(7,370)
Loss on disposal of assets	28,402		186		28,588
Stock-based compensation	—		3,433		3,433
Other expense	—		271		271
Other general and administrative expense (1)	—		9,937		9,937
Retention bonus and severance expense	75		21		96
Adjusted EBITDA	$	112,696	$	(12,362)	$	100,334

(1)Other general and administrative expense, (net of reimbursement from insurance carriers) relates to nonrecurring professional fees paid to external consultants in connection with the Company's pending SEC investigation and shareholder litigation, net of insurance recoveries. During the three and six months ended June 30, 2021, we received reimbursement of approximately $5.1 million and $6.7 million, respectively, from our insurance carriers in connection with the SEC investigation and shareholder litigation.

-11-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 6 - Net Loss Per Share

Basic net loss per common share is computed by dividing the net loss relevant to the common stockholders by the weighted average number of common shares outstanding during the period. Diluted net loss per common share uses the same net 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, 2021 and 2020, (in thousands, except for per share data):


	Three Months Ended June 30,
	2021		2020
Numerator (both basic and diluted)
Net loss relevant to common stockholders	$	(8,511)	$	(25,920)

Denominator
Denominator for basic loss per share	102,398		100,821
Dilutive effect of stock options	—		—
Dilutive effect of performance share units	—		—
Dilutive effect of restricted stock units	—		—
Denominator for diluted loss per share	102,398		100,821

Basic loss per share	$	(0.08)	$	(0.26)
Diluted loss per share	$	(0.08)	$	(0.26)



	Six Months Ended June 30,
	2021		2020
Numerator (both basic and diluted)
Net loss relevant to common stockholders	$	(28,886)	$	(33,724)

Denominator
Denominator for basic loss per share	101,976		100,754
Dilutive effect of stock options	—		—
Dilutive effect of performance share units	—		—
Dilutive effect of restricted stock units	—		—
Denominator for diluted loss per share	101,976		100,754

Basic loss per share	$	(0.28)	$	(0.33)
Diluted loss per share	$	(0.28)	$	(0.33)

-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, 2021 and 2020, respectively, have not been included in the calculation of diluted loss per common share for the three and six months ended June 30, 2021 and 2020 because they will be anti-dilutive to the calculation of diluted net loss per common share:


(In thousands)
	2021	2020
Stock options	995	4,224
Restricted stock units	1,380	1,269
Performance stock units	1,489	1,051
Total	3,864	6,544

Note 7 - Stock-Based Compensation

Stock Options

There were no new stock option grants during the six months ended June 30, 2021. As of June 30, 2021, the aggregate intrinsic value for our outstanding stock options was $3.0 million, and the aggregate intrinsic value for our exercisable stock options was $3.0 million. The aggregate intrinsic value for the exercised stock options during the six months ended June 30, 2021 was approximately $18.7 million. The remaining exercise period for both the outstanding and exercisable stock options as of June 30, 2021 was 4.1 years.

A summary of the stock option activity for the six months ended June 30, 2021 is presented below:


	Number of Shares	Weighted Average Exercise Price
Outstanding at January 1, 2021	4,200,341	$	4.82
Granted	—	$	—
Exercised	(3,128,798)	$	3.39
Forfeited	—	$	14.00
Expired	(76,306)	$	14.00
Outstanding at June 30, 2021	995,237	$	8.61
Exercisable at June 30, 2021	995,237	$	8.61

Restricted Stock Units

During the six months ended June 30, 2021, we granted a total of 787,287 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 share price of our common stock on the date of grant. As of June 30, 2021, the total unrecognized compensation expense for all RSUs was approximately $9.8 million, and is expected to be recognized over a weighted average period of approximately 2.1 years.

-13-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 7 - Stock-Based Compensation (Continued)

The following table summarizes RSUs activity during the six months ended June 30, 2021:


	Number of Shares	Weighted Average Grant Date Fair Value
Outstanding at January 1, 2021	1,165,369	$	8.50
Granted	787,287	$	9.85
Vested	(570,428)	$	8.58
Forfeited	(2,037)	$	10.96
Canceled	—	$	—
Outstanding at June 30, 2021	1,380,191	$	9.23

Performance Share Units

During the six months ended June 30, 2021, we granted 553,876 performance share units ("PSUs") to certain key employees and officers as new awards under the 2020 Incentive Plan. 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.

The following table summarizes information about PSUs activity during the six months ended June 30, 2021:


Period Granted	Target Shares Outstanding at January 1, 2021		Target Shares Granted		Target Shares Vested		Target Shares Forfeited		Target Shares Outstanding at June 30, 2021		Weighted Average Grant Date FV Per Share
2018	84,322		—		(84,322)		—		—		$	27.51
2019	126,318		—		—		—		126,318		$	27.49
2020	808,638		—		—		—		808,638		$	8.30
2021	—		553,876		—		—		553,876		$	15.37
Total	1,019,278		553,876		(84,322)		—		1,488,832		$	12.56
Weighted Average FV Per Share	$	12.27	$	15.37	$	27.51	$	—	$	12.56

The total stock-based compensation expense for the six months ended June 30, 2021 and 2020 for all stock awards was $5.4 million and $3.4 million, respectively. The total unrecognized stock-based compensation expense as of June 30, 2021 was approximately $20.9 million, and is expected to be recognized over a weighted average period of approximately 2.1 years.

-14-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 8 - Related-Party Transactions

Corporate Office Building

Prior to April 2020, the Company rented its corporate office building and the associated real property from an entity, in which a former executive officer of the Company has an equity interest for approximately $0.1 million per year. In April 2020, the Company acquired the corporate office building and the associated real property for approximately $1.5 million.

Operations and Maintenance Yards

The Company also leases five yards from an entity, in which certain former executive officers and a director of the Company have equity interests 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. The Company also leased its drilling yard from another entity, in which a certain former executive officer of the Company has an equity interest, for an annual lease expense of approximately $0.1 million. In November 2020, we terminated the drilling yard lease.

Equipment Rental and Other Services

The Company obtains equipment maintenance services from an entity that has a family relationship with an executive officer of the Company. During the six months ended June 30, 2021 and 2020, the Company incurred approximately $0 and $0.3 million, respectively, for equipment maintenance services associated with this related party.

At June 30, 2021 and December 31, 2020, the Company had no outstanding payables or receivables to or from the above related party transactions.

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.

Revenue from services provided to Pioneer (including idle fees) accounted for approximately $130.7 million and $64.3 million of our total revenue during the three months ended June 30, 2021 and 2020, respectively. Revenue from services provided to Pioneer (including idle fees) accounted for approximately $217.0 million and $191.6 million of our total revenue during the six months ended June 30, 2021 and 2020, respectively.

In connection with the Pioneer Pressure Pumping Acquisition, the Company agreed to reimburse Pioneer for our portion of the retention bonuses paid to former Pioneer employees that were subsequently employed by the Company. During the six months ended June 30, 2021 and 2020, the Company reimbursed Pioneer approximately $0 and $2.7 million, respectively.

As of June 30, 2021, the total accounts receivable due from Pioneer, including estimated unbilled receivable for services (including idle fees) we provided, amounted to approximately $84.9 million and the amount due to Pioneer was $0. As of December 31, 2020, the balance due from Pioneer for services (including idle fees) we provided amounted to approximately $41.7 million and the amount due to Pioneer was $0.

-15-

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. The lease is with an entity in which a former director of the Company has a noncontrolling equity ownership interest. During the six months ended June 30, 2021 and 2020, the Company made lease payments of approximately $0.1 million and $0.2 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. Effective January 1, 2019, the remaining lease term in our present value estimate of the minimum future lease payments was four years.

We accounted for our Real Estate Lease to be 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 real estate lease because we concluded that the accounting effect was insignificant. As of June 30, 2021, the weighted average discount rate and remaining lease term was 6.7% and 1.8 years, respectively.

As of June 30, 2021, the total operating lease right-of-use asset cost was approximately $1.2 million, and accumulated amortization was approximately $0.7 million. As of December 31, 2020, our total operating lease right-of-use asset cost was approximately $1.2 million, and accumulated amortization was $0.5 million. For the six months ended June 30, 2021 and 2020, we recorded operating lease cost of approximately $0.2 million and $0.2 million, respectively, in our statement of operations.

Finance Leases

Description of Ground Lease

In 2018, we entered into a ten year land lease contract (the "Ground Lease") with an exclusive option to purchase the land exercisable beginning one year from the commencement date of October 1, 2018 through the end of the contractual lease term. In March 2020, the Company exercised its option and purchased the land associated with the Ground Lease for approximately $2.5 million.

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, 2021 are as follows:



($ in thousands)	Totals
2021	$	190
2022	389
2023	98
Total undiscounted future lease payments	677
Less: amount representing interest	(40)
Present value of future lease payments (lease obligation)	$	637

The total cash paid for amounts included in the measurement of our operating lease liability during the six months ended June 30, 2021 was approximately $0.1 million. During the six months ended June 30, 2020, total cash paid for amounts included in the measurement of our operating and finance lease liabilities was approximately $0.2 million and $0.03 million, respectively.

-16-

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, 2021 and 2020 our short-term lease expense was approximately $0.3 million and $0.6 million, respectively.

In April 2021, we entered into a short-term lease arrangement to lease our gas turbine (the "Equipment Lease"') with a commencement date of June 1, 2021 through September 30, 2021. We have classified the Equipment Lease as an operating lease, and during the six months ended June 30, 2021, we recognized approximately $0.8 million in lease income recorded as part of our pressure pumping segment revenue on our statements of operations, and future lease income, which will be ratably recognized over the remaining lease period, is approximately $2.3 million.

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 businesses 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. As of June 30, 2021, the total outstanding contractual commitments entered into as part of normal course of business for supply of certain equipment and other assets was approximately $1.6 million. At June 30, 2021, the total remaining lease commitments for all of our short-term leases and lodging commitments was approximately $4.9 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 based on a fixed price per ton of unpurchased volumes. Our agreements with the Sand Suppliers expire at different times prior to December 31, 2025. During the six months ended June 30, 2021 and 2020, 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. One of the Sand Suppliers (“SandCo”) we entered into an agreement with to purchase sand ("Texas Sand") has an indirect relationship with a former executive officer of the Company, because beginning in 2018, the Texas Sand was sourced from a mine located on land owned by an entity in which the former executive officer of the Company has a 44% noncontrolling equity interest. The total sand purchased from SandCo during the three months ended March 31, 2020 (the period the former executive was associated with the Company) was approximately $5.3 million.

As of June 30, 2021, the Company had issued letters of credit of approximately $3.7 million under the ABL Credit Facility in connection with the Company’s casualty insurance policy.

Contingent Liabilities

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. In August 2020, the Company filed a motion to dismiss the Logan Lawsuit and in September 2020, the plaintiffs filed their opposition. In October 2020, the Company filed its reply brief in support of the motion to dismiss.

-17-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 10 - Commitments and Contingencies (Continued)

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 controls. In October 2020, the Company and other defendants filed motions to dismiss the Shareholder Derivative Lawsuit and in December 2020, the plaintiffs filed their opposition. In January 2021, the Company and other defendants filed reply briefs in support of the motions to dismiss.

In October 2019, the Company received a letter from the SEC indicating that the SEC had opened an investigation into the Company, which followed the SEC’s issuance of a formal order of investigation, and requesting that the Company provide certain information and documents, including documents related to the Company's expanded audit committee review and related events. The Company has cooperated and expects to continue to cooperate with the SEC’s investigation.

We are presently unable to predict the duration, scope or result of the Logan Lawsuit, the Shareholder Derivative Lawsuit, the SEC investigation, or any other related lawsuit or investigation. As of June 30, 2021, no provision was made by the Company in connection with these pending lawsuits and the SEC investigation as the final outcome cannot be reasonably estimated.

Environmental

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

Regulatory Audits

In 2020, the Texas Comptroller of Public Accounts 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, 2021, the audit is still at an early stage and the final outcome cannot be reasonably estimated.

In 2021, the Texas Comptroller of Public Accounts completed a routine audit of gross receipts, and sales, excise and use taxes for the periods of July 2015 through December 2018. The net refund to the Company from the sales and excise and use tax audit was approximately $2.1 million, which was recorded as part of other income in our statement of operations during the three months ended March 31, 2021.

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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 unconventional oil and natural gas resources. Our operations are primarily focused in the Permian Basin, where we have cultivated long-standing 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 area 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, 2021, was 1,423,000 HHP, which was comprised of 50,000 HHP of our new Tier IV Dynamic Gas Blending ("DGB") equipment, 1,265,000 HHP of conventional Tier II equipment and 108,000 HHP of our new DuraStim® electric hydraulic fracturing 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, in addition to several other changes to our customers' job designs, we believe that our available fleet capacity could decline if we decide to reconfigure our fleets to increase active HHP and backup HHP at the wellsites based on our customers' operational needs or as we retire and replace our conventional Tier II equipment.

In 2019, we entered into a purchase commitment for 108,000 HHP of DuraStim® electric powered hydraulic fracturing equipment. During the second quarter of 2021, we increased the scope of our DuraStim® equipment field trials by increasing the number of DuraStim® pumps deployed to our customer's wellsites. As we continue with our field trials, the ideal number of DuraStim® pumps that constitute a fleet will depend on a combination of factors, including the ultimate operating performance of DuraStim® pumps following the completion of testing, the particular shale formation where a well is completed, customer service requirements and job design. The Company had set a goal to fully commercialize its first DuraStim® fleet in the second half of 2021, subject to the completion of successful testing. Largely due to supply chain disruptions impacting the continuing testing process, the timing for the Company's ultimate decisions regarding DuraStim® commercialization may be extended We also have an option to purchase up to an additional 108,000 HHP of DuraStim® hydraulic fracturing equipment in the future through July 31, 2022. We currently have two gas turbines, that could provide electrical power to our DuraStim® fleet. The electrical power sources for future DuraStim® fleets are still being evaluated and could be supplied by the Company or a third-party supplier.

Our competitors include many large and small oilfield services companies, including Halliburton Company, Liberty Oilfield Services Inc., Nextier Oilfield Solutions Inc., Patterson-UTI Energy Inc., RPC, Inc., FTS International 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 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 our customers consider all of these factors, we believe price is a key factor in E&P companies' 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 capital requirements, and the continuing depressed pricing experienced by the service industry. 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 complex 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 are well-positioned to increase our activity in the Delaware sub-basin 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 Permian

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Basin specific operating conditions and the region's increasingly high-intensity well completions (including simultaneous hydraulic fracturing), 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. We believe our coiled tubing services create operational efficiencies for our customers and 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 supply chain disruptions and inflation , 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.

The global public health crisis associated with the COVID-19 pandemic has and could continue to have an adverse effect on global economic activity for the immediate future, has resulted in travel limitations, business closures and the institution of quarantining and other restrictions on movement and business operations in many communities. In 2020, the combined effect of COVID-19 and the energy industry disruptions led to a significant decline in WTI crude oil prices to approximately $21 per barrel at the end of March 2020. In 2021, with OPEC+ managing production levels, the development and administration of COVID-19 vaccines and the lifting of COVID-19 restrictions in certain areas (both in the United States and internationally), there has been a significant recovery in the energy industry and overall economic activities from its lowest point in 2020. However, the demand for crude oil increased rapidly during the first half of 2021 and is expected to continue to increase, but there has been no significant increase in oil and gas production in the United States, which has led to WTI crude oil prices increasing to approximately $72 as of July 28, 2021. The oil and gas industry has not fully recovered as evidenced by continued depressed pricing for most oilfield services, including our services, and shortages of skilled labor force in the Permian Basin. However, we still believe the Permian Basin, our primary area of operation, is the leading basin with the lowest break-even production cost in the United States. Accordingly, the Permian Basin rig count increased significantly from approximately 124 at the beginning of August 2020 to approximately 243 at the end of July 2021, according to Baker Hughes.

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.

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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, 2021
	Pressure Pumping		All Other		Total
Net 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(1)	—		(3,737)		(3,737)
Adjusted EBITDA	$	46,826	$	(11,133)	$	35,693

	Three Months Ended June 30, 2020
	Pressure Pumping		All Other		Total
Net loss	$	(13,528)	$	(12,392)	$	(25,920)
Depreciation and amortization	38,910		1,263		40,173
Interest expense	—		791		791
Income tax benefit	—		(6,460)		(6,460)
Loss on disposal of assets	8,587		147		8,734
Stock-based compensation	—		2,962		2,962
Other expense	—		267		267
Other general and administrative expense(1)	—		4,802		4,802
Retention bonus and severance expense	61		—		61
Adjusted EBITDA	$	34,030	$	(8,620)	$	25,410

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	Six Months Ended June 30, 2021
	Pressure Pumping		All Other		Total
Net 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

	Six Months Ended June 30, 2020
	Pressure Pumping		All Other		Total
Net loss	$	(9,220)	$	(24,504)	$	(33,724)
Depreciation and amortization	77,879		2,498		80,377
Impairment expense	15,559		1,095		16,654
Interest expense	1		2,071		2,072
Income tax benefit	—		(7,370)		(7,370)
Loss on disposal of assets	28,402		186		28,588
Stock-based compensation	—		3,433		3,433
Other expense	—		271		271
Other general and administrative expense (1)	—		9,937		9,937
Retention bonus and severance expense	75		21		96
Adjusted EBITDA	$	112,696	$	(12,362)	$	100,334

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Results of Operations

We conducted our business through three operating segments: hydraulic fracturing, cementing and coiled tubing. In March 2020, the Company shut down its flowback operating segment and subsequently disposed of the assets for approximately $1.6 million. In September 2020, the Company disposed of all of its drilling rigs and ancillary assets for approximately $0.5 million and shut down its drilling operations. 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, 2021 was $6.5 million and $11.6 million, respectively. The corporate administrative expense for the three and six months ended June 30, 2020 was $10.6 million and $20.9 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)
	2021			2020			$			%
Revenue	$	216,887		$	106,109		$	110,778		104.4	%
Less (Add):
Cost of services (1)	162,837			68,193			94,644			138.8	%
General and administrative expense (2)	17,529			20,331			(2,802)			(13.8)	%
Depreciation and amortization	33,243			40,173			(6,930)			(17.3)	%
Loss on disposal of assets	15,025			8,734			6,291			72.0	%
Interest expense	159			791			(632)			(79.9)	%
Other expense	302			267			35			13.1	%
Income tax benefit	(3,697)			(6,460)			(2,763)			(42.8)	%
Net loss	$	(8,511)		$	(25,920)		$	(17,409)		(67.2)	%

Adjusted EBITDA (3)	$	35,693		$	25,410		$	10,283		40.5	%
Adjusted EBITDA Margin (3)	16.5		%	23.9		%	(7.4)		%	(31.0)	%

Pressure pumping segment results of operations:
Revenue	$	213,461		$	103,815		$	109,646		105.6	%
Cost of services	$	159,490		$	65,991		$	93,499		141.7	%
Adjusted EBITDA (3)	$	46,826		$	34,030		$	12,796		37.6	%
Adjusted EBITDA Margin (4)	21.9		%	32.8		%	(10.9)		%	(33.2)	%

(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 idle fees of $1.0 million and $32.6 million for the three months ended June 30, 2021 and 2020, 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, 2021 Compared to the Three Months Ended June 30, 2020

Revenues. Revenues increased 104.4%, or $110.8 million, to $216.9 million during the three months ended June 30, 2021, as compared to $106.1 million during the three months ended June 30, 2020. Our pressure pumping segment revenues increased 105.6%, or $109.6 million, for the three months ended June 30, 2021, as compared to the three months ended June 30, 2020. The increases were primarily attributable to the significant increase in demand for pressure pumping services, following the rebound from the depressed oil prices and slowdown in economic activity resulting from the COVID-19 pandemic. The increase in demand for our pressure pumping services resulted in a significant increase in our average effectively utilized fleet count to approximately 13.1 active fleets during the three months ended June 30, 2021 from approximately 4.0 active fleets for the three months ended June 30, 2020. Included in our revenue for the three months ended June 30, 2021 and 2020 was revenue generated from idle fees charged to our customer of approximately $1.0 million and $32.6 million, respectively.

Revenues from services other than pressure pumping increased 49.3%, or $1.1 million, to $3.4 million for the three months ended June 30, 2021, as compared to $2.3 million for the three months ended June 30, 2020. The increase in revenue from services other than pressure pumping was primarily attributable to the increase in utilization experienced by our coiled tubing operations, which was driven by increased E&P completions activity following the rebound from the depressed oil prices and impact of the COVID-19 pandemic.

Cost of Services. Cost of services increased 138.8%, or $94.6 million, to $162.8 million for the three months ended June 30, 2021, as compared to $68.2 million during the three months ended June 30, 2020. Cost of services in our pressure pumping segment increased $93.5 million for the three months ended June 30, 2021, as compared to the three months ended June 30, 2020. These increases were primarily attributable to the significantly increased activity levels resulting from the increased demand for our services following the rebound from the depressed oil prices and economic slowdown caused by the COVID-19 pandemic that negatively impacted E&P completions activity in 2020. As a percentage of pressure pumping segment revenues (including idle fees), pressure pumping cost of services was 74.7% for the three months ended June 30, 2021, as compared to 63.6% for the three months ended June 30, 2020. Our revenue during the three months ended June 30, 2020, included significant idle fee revenue. Excluding idle fees revenue of $1.0 million and $32.6 million recorded during the three months ended June 30, 2021 and 2020, respectively, our pressure pumping cost of services as a percentage of pressure pumping revenues decreased to 75.1% during the three months ended June 30, 2021, as compared to 92.7% for the three months ended June 30, 2020. The decrease was a result of increased customer activity levels, which is consistent with our fleet utilization.

General and Administrative Expenses. General and administrative expenses decreased 13.8%, or $2.8 million, to $17.5 million for the three months ended June 30, 2021, as compared to $20.3 million for the three months ended June 30, 2020. The net decrease was primarily attributable to a decrease in (i) nonrecurring advisory and professional fees of $8.5 million paid to external consultants in connection with the Company's pending SEC investigation and shareholder litigation, (ii) legal and professional fees of $2.6 million, partially offset by net increases of $3.8 million in payroll expenses and 4.5 million in other remaining general and administrative expenses.

Depreciation and Amortization. Depreciation and amortization decreased 17.3%, or $6.9 million, to $33.2 million for the three months ended June 30, 2021, as compared to $40.2 million for the three months ended June 30, 2020. The decrease was primarily attributable to the decrease in our fixed asset base, partly attributable to the impairment of certain fixed assets in 2020.

Loss on Disposal of Assets. Loss on the disposal of assets increased 72.0%, or $6.3 million, to $15.0 million for the three months ended June 30, 2021, as compared to $8.7 million for the three months ended June 30, 2020. The increase was primarily attributable to the significant increase in utilization resulting in an increase in the operational intensity on our equipment. Upon sale or retirement of property and equipment, including certain major components of our pressure pumping equipment that are replaced, the cost and related accumulated depreciation are removed from the balance sheet and the net amount is recognized as loss on disposal of assets.

Interest Expense. Interest expense decreased 79.9%, or $0.6 million, to $0.2 million for the three months ended June 30, 2021, as compared to $0.8 million for the three months ended June 30, 2020. The decrease in interest expense was primarily attributable to the decrease in our average debt balance during the three months ended June 30, 2021 compared to the three months ended June 30, 2020. During the three months ended June 30, 2021, the Company had a zero debt balance, and the interest expense in the three months ended June 30, 2021, relates to the amortization of our capitalized loan origination cost.

Other Expense. There was no significant change in other expense. Other expense was $0.3 million for the three months ended June 30, 2021, as compared to $0.3 million for the three months ended June 30, 2020. A significant portion of our other expense consists of our lender's commitment fees.

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Income Taxes. Total income tax benefit was $3.7 million resulting in an effective tax rate of 30.3% for the three months ended June 30, 2021, as compared to income tax expense of $6.5 million or an effective tax rate of 20.0% for the three months ended June 30, 2020. The income tax benefit recorded in the three months ended June 30, 2021 is primarily attributable to the Company projecting a pre-tax loss in 2021 as compared to pre-tax income in 2020. Furthermore, the change in the effective tax rate from 20.0% to 30.3% in the three months ended June 30, 2021 was primarily attributable to nondeductible expenses and discrete items such as stock compensation expense reducing the benefit recorded for the pre-tax loss.

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)
	2021			2020			$			%
Revenue	$	378,345		$	501,178		$	(122,833)		(24.5)	%
Less (Add):
Cost of services (1)	286,215			369,041			(82,826)			(22.4)	%
General and administrative expense (2)	37,731			45,269			(7,538)			(16.7)	%
Depreciation and amortization	66,721			80,377			(13,656)			(17.0)	%
Impairment expense	—			16,654			(16,654)			(100.0)	%
Loss on disposal of assets	28,076			28,588			(512)			(1.8)	%
Interest expense	335			2,072			(1,737)			(83.8)	%
Other (income)/expense	(1,487)			271			1,758			(648.7)	%
Income tax benefit	(10,360)			(7,370)			2,990			40.6	%
Net loss	$	(28,886)		$	(33,724)		$	(4,838)		(14.3)	%

Adjusted EBITDA (3)	$	55,709		$	100,334		$	(44,625)		(44.5)	%
Adjusted EBITDA Margin (3)	14.7		%	20.0		%	(5.3)		%	(26.5)	%

Pressure pumping segment results of operations:
Revenue	$	371,652		$	490,735		$	(119,083)		(24.3)	%
Cost of services	$	279,258		$	360,215		$	(80,957)		(22.5)	%
Adjusted EBITDA (3)	$	78,697		$	112,696		$	(33,999)		(30.2)	%
Adjusted EBITDA Margin (4)	21.2		%	23.0		%	(1.8)		%	(7.8)	%

(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 idle fees of $5.3 million and $34.1 million for the six months ended June 30, 2021 and 2020, respectively.

Six Months Ended June 30, 2021 Compared to the Six Months Ended June 30, 2020

Revenues. Revenues decreased 24.5%, or $122.8 million, to $378.3 million during the six months ended June 30, 2021, as compared to $501.2 million during the six months ended June 30, 2020. Our pressure pumping segment revenues decreased 24.3%, or $119.1 million, for the six months ended June 30, 2021, as compared to the six months ended June 30, 2020. The decreases were primarily attributable to the significant pricing discounts we provided our customers beginning April 2020, and in part due to substantially all of our customers directly sourcing certain consumables like sand, chemical, and diesel. Our average effectively utilized fleet count during the six months ended June 30, 2021, was approximately 11.7 active fleets, compared to 11.1 during the six months ended June 30, 2020. Included in our revenue for the six months ended June 30, 2021 and 2020 was revenue generated from idle fees charged to our customer of approximately $5.3 million and $34.1 million, respectively.

Revenues from services other than pressure pumping decreased 35.9%, or $3.8 million, to $6.7 million for the six months ended June 30, 2021, as compared to $10.4 million for the six months ended June 30, 2020. The decrease in revenues from services other than pressure pumping was primarily attributable to the disposal of our flowback operations in March 2020.

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Cost of Services. Cost of services decreased 22.4%, or $82.8 million, to $286.2 million for the six months ended June 30, 2021, as compared to $369.0 million during the six months ended June 30, 2020. Cost of services in our pressure pumping segment decreased $81.0 million for the six months ended June 30, 2021, as compared to the six months ended June 30, 2020. These decreases were primarily attributable to the significant reduction in the consumables (like sand, chemical and diesel) we sourced for customers and also our cost optimization strategies following the depressed oil prices and economic slowdown caused by the COVID-19 pandemic. As a percentage of pressure pumping segment revenues (including idle fees), pressure pumping cost of services increased to 75.1% for the six months ended June 30, 2021, as compared to 73.4% for the six months ended June 30, 2020. The increase in our cost of services percentage was primarily attributable to pricing pressure on our services resulting in customer discounts, partially offset by the idle fees revenue. Excluding idle fees revenue of $5.3 million and $34.1 million recorded during the six months ended June 30, 2021 and 2020, respectively, our pressure pumping cost of services as a percentage of pressure pumping revenues decreased to 76.2% during the six months ended June 30, 2021, as compared to 78.9% for the six months ended June 30, 2020. The decrease was a result of increased operational efficiencies and reduction in certain consumables provided to customers.

General and Administrative Expenses. General and administrative expenses decreased 16.7%, or $7.5 million, to $37.7 million for the six months ended June 30, 2021, as compared to $45.3 million for the six months ended June 30, 2020. The net decrease was primarily attributable to a decrease in (i) nonrecurring advisory and professional fees of $14.6 million paid to external consultants in connection with the Company's pending SEC investigation and shareholder litigation, (ii) legal and professional fees of approximately $2.7 million, which was partially offset by a net increase of approximately $9.0 million paid in payroll expenses, and $0.8 million in other remaining general and administrative expenses.

Depreciation and Amortization. Depreciation and amortization decreased 17.0%, or $13.7 million, to $66.7 million for the six months ended June 30, 2021, as compared to $80.4 million for the six months ended June 30, 2020. The decrease was primarily attributable to the overall decrease in our fixed asset base in 2020, partly attributable to the impairment of certain fixed assets in 2020.

Impairment Expense. There was no impairment expense during the six months ended June 30, 2021. During the six months ended June 30, 2020 depressed market conditions, crude oil prices and negative near-term outlook for the utilization of certain of our equipment resulted in the Company recording an impairment expense of $16.7 million, of which $9.4 million relates to goodwill impairment and $7.2 million relates to property and equipment impairment.

Loss on Disposal of Assets. Loss on the disposal of assets was relatively flat with a slight decrease of 1.8%, or $0.5 million, to $28.1 million for the six months ended June 30, 2021, as compared to $28.6 million for six months ended June 30, 2020.

Interest Expense. Interest expense decreased 83.8%, or $1.7 million, to $0.3 million for the six months ended June 30, 2021, as compared to $2.1 million for the six months ended June 30, 2020. The decrease in interest expense was primarily attributable to the decrease in our average debt balance during the six months ended June 30, 2021 compared to the six months ended June 30, 2020.

Other (Income)/Expense. Other income increased to approximately $1.5 million for the six months ended June 30, 2021, as compared to $0.3 million in expense for the six months ended June 30, 2020. The increase in other income is primarily attributable to the net refund of approximately $2.1 million to the Company from the sales and excise and use tax audit and partially offset by an expense related to our lender's commitment fees during six months ended June 30, 2021, as compared to the six months ended June 30, 2020.

Income Taxes. Total income tax benefit was $10.4 million resulting in an effective tax rate of 26.4% for the six months ended June 30, 2021, as compared to income tax expense of $7.4 million or an effective tax rate of 17.9% for the six months ended June 30, 2020. The income tax benefit recorded in the six months ended June 30, 2021 is primarily attributable to the Company projecting a pre-tax loss in 2021 as compared to pre-tax income in 2020. Furthermore, the change in the effective tax rate from 17.9% to 26.4% in the six months ended June 30, 2021 was primarily attributable to nondeductible expenses and discrete items such as stock compensation expense reducing the benefit recorded for the pre-tax loss.

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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, if any. Our primary uses of cash will be to continue to fund our operations, support growth opportunities and satisfy future debt payments, if any. Our borrowing base, as redetermined monthly, is tied to 85.0% of eligible accounts receivable. Changes to our operational activity levels 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. We believe our remaining monthly availability under our ABL Credit Facility will be adversely impacted if the current depressed oil and gas market conditions continue or worsen.

As of June 30, 2021, we had no borrowings under our ABL Credit Facility, and our total liquidity was approximately $140.8 million, consisting of cash and cash equivalents of $72.7 million and $68.1 million of availability under our ABL Credit Facility.

As of July 28, 2021, our total liquidity was approximately $140.0 million, consisting of cash and cash equivalents of $70.8 million and $69.2 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 led by depressed WTI crude oil prices, the Company experienced a significant decrease in its liquidity. In 2021, we have experienced a gradual recovery in the energy industry and crude oil prices resulting from the reduction in the COVID-19 infection rate following the administration of COVID-19 vaccines, which we believe will improve the demand for crude oil and consequently the demand for our pressure pumping services, thus improving our future liquidity. However, the current market conditions resulting from the COVID-19 pandemic could rapidly change and there could be a new outbreak of a COVID-19 variant or the vaccines may not be as effective as anticipated, which could negatively impact the demand for our services and our future revenue, results of operations and cash flows.

There can be no assurance that 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 ABL Credit Facility, as amended, has a total borrowing capacity of $300 million (subject to the Borrowing Base limit), with a maturity date of December 19, 2023. The ABL Credit Facility has a borrowing base of 85% of monthly eligible accounts receivable less customary reserves (the "Borrowing Base"). The Borrowing Base as of June 30, 2021 was approximately $71.8 million and was approximately $72.9 million as of July 28, 2021. 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) $22.5 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.

In July 2017, the United Kingdom's Financial Conduct Authority, which regulates LIBOR, announced that it intends to phase out LIBOR by the end of 2021. At the present time, the ABL Credit Facility is subject to LIBOR rates but has a term that extends beyond the end of 2021 when LIBOR will be phased out. We have not yet pursued any technical amendment or other contractual alternative to address this matter. We are currently evaluating the potential impact of eventual replacement of the LIBOR interest rate, although our ABL Credit Facility agreement allows us to elect an alternative rate (base rate) to accrue interest.

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Future Sources and Use of Cash and Contractual Obligations

Our future primary use of cash will be to fund capital expenditures. Capital expenditures for 2021 are projected to be primarily related to maintenance capital expenditures to support our existing assets, including costs to convert our existing conventional Tier II equipment to lower emissions Tier IV DGB equipment.

We expect that our currently anticipated capital expenditures will be funded by existing cash, cash flows from operations, and, if needed, borrowings under our ABL Credit Facility. However, as noted elsewhere in this quarterly report, we will continually evaluate opportunities to improve our service offerings and other investment and acquisition opportunities that we believe would enhance the competitiveness of our business. Depending upon market conditions and other factors, we may issue equity and debt securities or take other actions necessary to fund our future investment or acquisitions.

In addition, we have option agreements with our equipment manufacturer to purchase additional 108,000 HHP of DuraStim® hydraulic fracturing equipment through July 31, 2022. We believe the cost to acquire the DuraStim® hydraulic fracturing equipment will be comparable to our previously purchased DuraStim® hydraulic fracturing equipment. Currently, because of ongoing testing and commercialization efforts, we cannot reasonably determine whether or not we will exercise these options before they expire.

In the normal course of business, we enter into various contractual obligations and incur expenses in connection with routine growth and maintenance capital expenditures that impact our future liquidity. There were no other known future material contractual obligations as of June 30, 2021.

Cash and Cash Flows

The following table sets forth the historical cash flows for the six months ended June 30, 2021 and 2020:


	Six Months Ended June 30,
(in thousands)	2021		2020

Net cash provided by operating activities	$	61,480	$	96,910
Net cash used in investing activities	$	(50,920)	$	(78,025)
Net cash used in financing activities	$	(6,631)	$	(130,615)

Cash Flows From Operating Activities

Net cash provided by operating activities was $61.5 million for the six months ended June 30, 2021, compared to net cash provided by operating activities of $96.9 million for the six months ended June 30, 2020. The net decrease of $35.4 million was primarily due to decreased profitability and the timing of collections of our receivables from customers and payments to vendors. Our effectively utilized fleet count was relatively flat with a slight increase to approximately 11.7 active fleets during the six months ended June 30, 2021 from approximately 11.1 active fleets for the six months ended June 30, 2020.

Cash Flows From Investing Activities

Net cash used in investing activities decreased to $50.9 million for the six months ended June 30, 2021, from $78.0 million for the six months ended June 30, 2020. The decrease was primarily attributable to the lower maintenance capital expenditures driven primarily by equipment redundancies.

Cash Flows From Financing Activities

Net cash used in financing activities was $6.6 million for the six months ended June 30, 2021, and net cash provided by financing activities was $130.6 million for the six months ended June 30, 2020. The net decrease in cash from financing activities during the six months ended June 30, 2021 was primarily driven by no repayments of borrowings under our ABL Credit Facility, compared to repayment of borrowings under our ABL Credit Facility of $130 million during the six months ended June 30, 2020.

Off-Balance Sheet Arrangements

We had no off-balance sheet arrangements as of June 30, 2021.

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Critical Accounting Policies and Estimates

There have been no material changes during the six months ended June 30, 2021 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, 2021, 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, 2021.

Changes in Internal Control over Financial Reporting

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) occurred during the quarter ended June 30, 2021 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).
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. Section1350, 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 5, 2021

By:

/s/ Phillip A. Gobe

Phillip A. Gobe

Chief Executive Officer and Chairman of the Board

(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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Form: 10-Q

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