

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

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

Large accelerated filer

☒☐

Accelerated filer

☐☒

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

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

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

The number of the registrant’s common shares, par value $0.001 per share, outstanding ~~at July 31, 2020,~~at May 3, 2021, was ~~100,898,445.~~102,280,331.

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 ~~Quarterly Report on~~ Form 10-Q are forward-looking statements within the meaning of Section 21E of the Securities and Exchange ~~Act.~~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 ~~recent~~ outbreak of the novel coronavirus ~~(“COVID-19”~~("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 current significant surplus in the supply of oil and actions by the members of the Organization of the Petroleum Exporting Countries ~~(“OPEC”~~("OPEC") and Russia (together with OPEC and other allied producing countries, ~~“OPEC+”~~"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;

•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;

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

•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;

•~~technological changes;~~


•	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 ~~existing and future laws and governmental regulations (or the interpretation thereof);~~

~~the effects of~~ current and future litigation, including the Logan Lawsuit and the Shareholder Derivative Lawsuit (each defined herein);

-ii-

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

~~-ii-~~

•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;

~~the material weaknesses in our internal controls over financial reporting~~ and disclosure controls and procedures, as well as the implementation and effectiveness of the Company's remediation plan described under Part I, Item 4, “Controls and Procedure” in this Form 10-Q; 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, ~~2019,~~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.

-iii-

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)

(Unaudited)


	March 31, 2021		December 31, 2020
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	55,859	$	68,772
Accounts receivable - net of allowance for credit losses of $0 and $1,497, respectively	110,386		84,244
Inventories	2,329		2,729
Prepaid expenses	7,853		11,199
Other current assets	14		782
Total current assets	176,441		167,726
PROPERTY AND EQUIPMENT - net of accumulated depreciation	866,050		880,477
OPERATING LEASE RIGHT-OF-USE ASSETS	636		709
OTHER NONCURRENT ASSETS:
Other noncurrent assets	1,656		1,827
Total other noncurrent assets	1,656		1,827
TOTAL ASSETS	$	1,044,783	$	1,050,739
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	108,931	$	79,153
Operating lease liabilities	342		334
Accrued and other current liabilities	19,186		24,676
Total current liabilities	128,459		104,163
DEFERRED INCOME TAXES	68,677		75,340
NONCURRENT OPERATING LEASE LIABILITIES	378		465
Total liabilities	197,514		179,968
COMMITMENTS AND CONTINGENCIES (Note 10)	0		0
SHAREHOLDERS’ EQUITY:
Preferred stock, $0.001 par value, 30,000,000 shares authorized, NaN issued, respectively	0		0
Common stock, $0.001 par value, 200,000,000 shares authorized, 102,057,815 and 100,912,777 shares issued, respectively	102		101
Additional paid-in capital	831,987		835,115
Retained earnings	15,180		35,555
Total shareholders’ equity	847,269		870,771
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	1,044,783	$	1,050,739

See notes to condensed consolidated financial statements.

-1-

June 30, 2020 December 31, 2019
ASSETS
CURRENT ASSETS:
Cash and cash equivalents $ 37,306
$ 149,036
Accounts receivable - net of allowance for credit losses of $1,497 and $1,049, respectively 65,554
212,183
Inventories 2,805
2,436
Prepaid expenses 5,061
10,815
Other current assets 1,103
1,121
Total current assets 111,829
375,591
PROPERTY AND EQUIPMENT - net of accumulated depreciation 978,749
1,047,535
OPERATING LEASE RIGHT-OF-USE ASSETS 851
989
OTHER NONCURRENT ASSETS:
Goodwill —
9,425
Other noncurrent assets 2,173
2,571
Total other noncurrent assets 2,173
11,996
TOTAL ASSETS $ 1,093,602
$ 1,436,111
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable $ 31,233
$ 193,096
Operating lease liabilities 317
302
Finance lease liabilities —
2,831
Accrued and other current liabilities 27,719
36,343
Accrued interest payable —
394
Total current liabilities 59,269
232,966
DEFERRED INCOME TAXES 95,268
103,041
LONG-TERM DEBT —
130,000
NONCURRENT OPERATING LEASE LIABILITIES 636
799
Total liabilities 155,173
466,806
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,100,889,230 and 100,624,099 shares issued, respectively 101
101
Additional paid-in capital 829,477
826,629
Retained earnings 108,851
142,575
Total shareholders’ equity 938,429
969,305
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY $ 1,093,602
$ 1,436,111

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)

(Unaudited)


	Three Months Ended March 31,
	2021		2020
REVENUE - Service revenue	$	161,458	$	395,069
COSTS AND EXPENSES
Cost of services (exclusive of depreciation and amortization)	123,378		300,848
General and administrative (inclusive of stock-based compensation)	20,201		24,937
Depreciation and amortization	33,478		40,205
Impairment expense	0		16,654
Loss on disposal of assets	13,052		19,854
Total costs and expenses	190,109		402,498
OPERATING LOSS	(28,651)		(7,429)
OTHER INCOME (EXPENSE):
Interest expense	(176)		(1,281)
Other income (expense)	1,789		(3)
Total other income (expense)	1,613		(1,284)
LOSS BEFORE INCOME TAXES	(27,038)		(8,713)
INCOME TAX BENEFIT	6,663		909
NET LOSS	$	(20,375)	$	(7,804)

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

WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic	101,550		100,687
Diluted	101,550		100,687

See notes to condensed consolidated financial statements.

-2-

Three Months Ended June 30, Six Months Ended June 30,
2020 2019 2020 2019
REVENUE - Service revenue $ 106,109
$ 529,494
$ 501,178
$ 1,075,673
COSTS AND EXPENSES
Cost of services (exclusive of depreciation and amortization) 68,193
386,218
369,041
767,741
General and administrative (inclusive of stock-based compensation) 20,331
27,889
45,269
46,414
Depreciation and amortization 40,173
35,482
80,377
68,599
Impairment expense —
—
16,654
—
Loss on disposal of assets 8,734
31,198
28,588
50,425
Total costs and expenses 137,431
480,787
539,929
933,179
OPERATING INCOME (LOSS) (31,322 ) 48,707
(38,751 ) 142,494
OTHER EXPENSE:
Interest expense (791 ) (2,026 ) (2,072 ) (3,928 )
Other expense (267 ) (276 ) (271 ) (464 )
Total other expense (1,058 ) (2,302 ) (2,343 ) (4,392 )
INCOME (LOSS) BEFORE INCOME TAXES (32,380 ) 46,405
(41,094 ) 138,102
INCOME TAX (EXPENSE) BENEFIT 6,460
(10,272 ) 7,370
(32,164 )
NET INCOME (LOSS) $ (25,920 ) $ 36,133
$ (33,724 ) $ 105,938

NET INCOME (LOSS) PER COMMON SHARE:
Basic $ (0.26 ) $ 0.36
$ (0.33 ) $ 1.06
Diluted $ (0.26 ) $ 0.35
$ (0.33 ) $ 1.02

WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic 100,821
100,425
100,754
100,329
Diluted 100,821
104,379
100,754
104,181

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY

(In thousands)

(Unaudited)


	Three Months Ended March 31, 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)		—		0
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


	Three Months Ended March 31, 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	—		0		—		0
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

See notes to condensed consolidated financial statements.

-3-

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

Six Months Ended June 30, 2019
Common Stock
Shares Amount Additional Paid-In Capital Retained Earnings (Accumulated Deficit) Total
BALANCE - January 1, 2019 100,190
$ 100
$ 817,690
$ (20,435 ) 797,355
Stock-based compensation cost —
—
1,829
—
1,829
Issuance of equity awards, net 104
—
552
—
552
Net income —
—
—
$ 69,805
69,805
BALANCE - March 31, 2019 100,294
$ 100
$ 820,071
$ 49,370
$ 869,541
Stock-based compensation cost —
—
2,840
—
2,840
Issuance of equity awards, net 257
1
522
—
523
Net income —
—
—
36,133
36,133
BALANCE - June 30, 2019 100,551
101
823,433
85,503
909,037

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)


	Three Months Ended March 31,
	2021		2020
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(20,375)	$	(7,804)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization	33,478		40,205
Impairment expense	0		16,654
Deferred income tax benefit	(6,663)		(1,312)
Amortization of deferred debt issuance costs	134		135
Stock-based compensation	2,487		471
Provision for credit losses	0		4,291
Loss on disposal of assets	13,052		19,854
Changes in operating assets and liabilities:
Accounts receivable	(25,698)		(14,486)
Other current assets	325		1,138
Inventories	401		(860)
Prepaid expenses	3,383		2,920
Accounts payable	18,579		10,080
Accrued and other current liabilities	(2,095)		(9,431)
Accrued interest	0		(131)
Net cash provided by operating activities	17,008		61,724
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(22,494)		(47,290)
Proceeds from sale of assets	224		733
Net cash used in investing activities	(22,270)		(46,557)
CASH FLOWS FROM FINANCING ACTIVITIES:
Repayments of borrowings	0		(20,000)
Payment of finance lease obligation	0		(30)
Repayments of insurance financing	(2,037)		0
Tax withholdings paid for net settlement of equity awards	(5,614)		(456)
Net cash used in financing activities	(7,651)		(20,486)
NET DECREASE IN CASH AND CASH EQUIVALENTS	(12,913)		(5,319)
CASH AND CASH EQUIVALENTS - Beginning of period	68,772		149,036
CASH AND CASH EQUIVALENTS - End of period	$	55,859	$	143,717

See notes to condensed consolidated financial statements.

-4-

Six Months Ended June 30,
2020 2019
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) $ (33,724 ) $ 105,938
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization 80,377
68,599
Impairment expense 16,654
—
Deferred income tax expense (benefit) (7,773 ) 30,937
Amortization of deferred debt issuance costs 270
269
Stock-based compensation 3,433
4,669
Provision for credit losses 448
475
Loss on disposal of assets 28,588
50,425
Changes in operating assets and liabilities:
Accounts receivable 146,181
(168,999 )
Other current assets 1,613
596
Inventories (369 ) 1,274
Prepaid expenses 5,833
1,417
Accounts payable (135,592 ) 42,533
Accrued and other current liabilities (8,635 ) 12,299
Accrued interest (394 ) 419
Net cash provided by operating activities 96,910
150,851
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures (80,702 ) (325,881 )
Proceeds from sale of assets 2,677
1,547
Net cash used in investing activities (78,025 ) (324,334 )
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings —
90,000
Repayments of borrowings (130,000 ) (10,000 )
Payment of finance lease obligation (30 ) (123 )
Repayments of insurance financing —
(3,890 )
Proceeds from exercise of equity awards —
1,075
Tax withholdings paid for net settlement of equity awards
(585 ) —
Net cash provided by (used in) financing activities (130,615 ) 77,062
NET DECREASE IN CASH AND CASH EQUIVALENTS (111,730 ) (96,421 )
CASH AND CASH EQUIVALENTS - Beginning of period 149,036
132,700
CASH AND CASH EQUIVALENTS - End of period $ 37,306
$ 36,279

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"~~(the "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, ~~2019~~2020 included in our Form 10-K filed with the SEC (our "Form 10-K").

~~Risks and Uncertainties~~

As an oilfield services company, we are exposed to a number of risks and uncertainties that are inherent to our industry. In addition to such industry-specific risks, the global public health crisis associated with the novel coronavirus (“COVID-19”) pandemic has, and is anticipated to continue to have, an adverse effect on global economic activity for the immediate future and has resulted in travel restrictions, business closures and the institution of quarantining and other restrictions on movement in many communities. The slowdown in global economic activity attributable to the COVID-19 pandemic has resulted in a dramatic decline in the demand for energy, which directly impacts our industry and the Company. In addition, global crude oil prices experienced a collapse starting in early March 2020 as a direct result of failed negotiations between the Organization of the Petroleum Exporting Countries (“OPEC”) and Russia. In response to the global economic slowdown, OPEC had recommended a decrease in production levels in order to accommodate reduced demand. Russia rejected the recommendation of OPEC as a concession to U.S. producers. After the failure to reach an agreement, Saudi Arabia, a dominant member of OPEC, and other Persian Gulf OPEC members announced intentions to increase production and offer price discounts to buyers in certain geographic regions.

As the breadth of the COVID-19 health crisis expanded throughout the month of March 2020 and governmental authorities implemented more restrictive measures to limit person-to-person contact, global economic activity continued to decline commensurately. The associated impact on the energy industry has been adverse and continued to be exacerbated by the unresolved conflict regarding production. In the second week of April 2020, OPEC, Russia and certain other petroleum producing nations (“OPEC+”), reconvened to discuss the matter of production cuts in light of unprecedented disruption and supply and demand imbalances that expanded since the failed negotiations in early March 2020. Tentative agreements were reached to cut production by up to 10 million barrels of oil per day with allocations to be made among the OPEC+ participants. Some of these production cuts went into effect in the first half of May 2020, however, commodity prices remain depressed as a result of an increasingly utilized global storage network and near-term demand loss attributable to the COVID-19 health crisis and related economic slowdown.

The combined effect of COVID-19 and the energy industry disruptions led to a decline in WTI crude oil prices of approximately 67 percent from the beginning of January 2020, when prices were approximately $62 per barrel, through the end of March 2020, when they were just above $20 per barrel. Overall crude oil price volatility has continued despite apparent agreement among OPEC+ regarding production cuts and as of July 31, 2020, the WTI price for a barrel of crude oil was approximately $41.

Despite a significant decline in drilling and completion activities by U.S. producers starting in mid-March 2020, domestic supply is exceeding demand, which has led to significant operational stress with respect to capacity limitations associated with storage, pipeline and refining infrastructure, particularly within the Gulf Coast region. The combined effect of the aforementioned factors is anticipated to have an adverse impact on the industry in general and our operations specifically.

Since March 2020, we initiated several actions to mitigate the anticipated adverse economic conditions for the immediate future and to support our financial position and liquidity. The more significant actions that we have taken included: (i) canceling substantially all of our growth capital projects, (ii) significantly reducing our maintenance expenditures and field level consumable costs, (iii) reducing our workforce to follow our activity levels, (iv) efforts to manage our compensation costs, such as compensation reductions and short-term management of work schedules to minimize overtime costs and (v) negotiating more favorable payment terms with certain of our larger vendors and proactively managing our portfolio of accounts receivable.

~~PROPETRO HOLDING CORP.~~

N~~OTES~~TOC~~ONDENSED~~C~~ONSOLIDATED~~F~~INANCIAL~~S~~TATEMENTS~~

~~(Unaudited)~~

~~Note 1 - Basis of Presentation (Continued)~~

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~~our principal activities, ~~separated~~aggregated into our 1 reportable ~~segment~~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, ~~method,~~ 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 isor 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 ~~our~~ coiled tubing ~~and drilling,~~operations, which are ~~all~~ downhole well ~~stimulation and~~ completion/remedial services. The performance obligation for ~~each of the~~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, 2020~~March 31, 2021 and December 31, ~~2019,~~2020, accrued revenue (unbilled receivable) included as part of our accounts receivable was ~~$6.5~~$14.0 million and ~~$37.0~~$8.6 million, respectively. At ~~June 30, 2020,~~March 31, 2021, the transaction price allocated to the remaining performance obligation for our partially

-5-

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 1 - Basis of Presentation (Continued)

completed hydraulic fracturing operations was ~~$4.3~~ $16.2 million, which is expected to be completed and recognized inwithin one month following the current period balance sheet date, in our pressure pumping reportable segment.

Allowance for Credit Losses

As of ~~June 30, 2020,~~March 31, 2021, the Company had ~~$1.5 million~~ 0 allowance for credit losses. During the three months ended March 31, 2021 the Company fully wrote off certain receivables and the associated allowance for credit losses because it was reasonably certain that the receivables will not be recovered. Our allowance for credit losses is based on the evaluation of both our historic collection experience and the expected impact of currently 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 ~~further~~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,

~~PROPETRO HOLDING CORP.~~

N~~OTES~~TOC~~ONDENSED~~C~~ONSOLIDATED~~F~~INANCIAL~~S~~TATEMENTS~~

~~(Unaudited)~~

~~Note 1 - Basis of Presentation (Continued)~~

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 ~~for~~ the ~~six~~three months ended ~~June 30, 2020.~~March 31, 2021:

($ in thousands)

Balance - January 1, 2020 $ 1,049
Provision for credit losses during the period 4,291
Provision for credit losses no longer required (3,843 )
Balance - June 30, 2020 $ 1,497


($ in thousands)

Balance - January 1, 2021	$	1,497
Provision for credit losses during the period	0
Write-off during the period	(1,497)
Balance - March 31, 2021	$	0

Note 2 - Recently Issued Accounting Standards

Recently Issued Accounting Standards Adopted in ~~2020~~

~~In June 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standard Update ("ASU") No. 2016-13,~~ ~~Financial Instruments-Credit Losses (Topic 326)~~: ~~Measurement of Credit Losses on Financial Instruments~~, which introduces a new impairment model for financial instruments that is based on expected credit losses rather than incurred credit losses. The new impairment model applies to most financial assets, including trade accounts receivable and lease receivables. In November 2018, the FASB issued ASU No. 2018-19, ~~Codification Improvements to Topic 326, Financial Instruments-Credit Losses, which clarified that receivables arising from operating leases are not within the scope of ASC 326-20,~~ ~~Financial Instruments-Credit Losses-Measured at Amortized Cost~~, and should be accounted for in accordance with ASC 842. ASU 2016-13 and ASU 2018-19 are effective for annual periods beginning after December 15, 2019. Effective January 1, 2020, the Company adopted ASU 2016-13 using the modified-retrospective approach, which allows for a cumulative-effect adjustment to the consolidated condensed balance sheet as of the beginning of the first reporting period in which the guidance is effective. Periods prior to the adoption date that are presented for comparative purposes are not adjusted. The Company continuously evaluates customers based on risk characteristics, such as historical losses and current economic conditions. Due to the cyclical nature of the oil and gas industry, the Company often evaluates its customers’ estimated losses on a combination of historical losses and on case-by-case basis. There was no material impact to our condensed consolidated financial statements as a result of adoption of ASU 2016-13.

~~In August 2018, the FASB issued ASU No. 2018-13,~~ ~~Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement~~, which eliminates, adds and modifies certain disclosure requirements for fair value measurements. The Company adopted ASU 2018-13 on January 1, 2020 and determined the adoption of this standard did not impact the Company’s condensed consolidated financial statements.

~~In January 2017, the FASB issued ASU No. 2017-04,~~ ~~Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment~~, which removes the requirement to compare the implied fair value of goodwill with its carrying amount as part of step two of the goodwill impairment test. As a result, under this ASU, an entity would recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value, although the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. This ASU is effective for impairment tests in fiscal years beginning after December 15, 2019, on a prospective basis. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. Effective January 1, 2020, we adopted this guidance and the adoption did not materially affect the Company's condensed consolidated financial statements. See Note 3 for additional disclosures relating to our goodwill impairment.

~~Recently Issued Accounting Standards Not Yet Adopted in 2020~~2021

In December 2019, the ~~FASB~~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. ~~The Company does~~Effective January 1, 2021, we adopted this guidance and the adoption did not ~~expect ASU 2019-12 to have a material effect on~~materially affect the Company’s condensed consolidated financial statements.

~~PROPETRO HOLDING CORP.~~

N~~OTES~~TOC~~ONDENSED~~C~~ONSOLIDATED~~F~~INANCIAL~~S~~TATEMENTS~~

~~(Unaudited)~~

~~Note 2 -~~ Recently Issued Accounting Standards ~~(Continued)~~

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.~~statements and does not expect ASU 2020-04 to have a material effect 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

-6-

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 3 - Fair Value Measurement (Continued)

use in pricing the asset or liability developed based on the best information available in the circumstances. The hierarchy is broken down into three levels based on the observability of inputs as follows:

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

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

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. The estimated fair value of our financial instruments at ~~June 30, 2020~~March 31, 2021 and December 31, ~~2019~~2020 approximated or equaled their carrying values as reflected in our condensed consolidated balance sheets.

Assets Measured at Fair Value on a Nonrecurring Basis

~~Assets measured at fair value on a nonrecurring basis at June 30, 2020 and December~~ There was 0 impairment of assets during the three months ended March 31, ~~2019, respectively, are set forth below:~~

($ in thousands)

Estimated fair value measurements
Balance Quoted prices in active market
(Level 1) Significant other observable inputs (Level 2) Significant other unobservable inputs (Level 3) Total gains
(losses)
June 30, 2020:
Property and equipment, net $ —
$ —
$ —
$ —
$ —
Goodwill $ —
$ —
$ —
$ —
$ —
December 31, 2019:
Property and equipment, net $ 2,000
$ —
$ 2,000
$ —
$ (3,405 )
Goodwill $ —
$ —
$ —
$ —
$ —

~~PROPETRO HOLDING CORP.~~

N~~OTES~~TOC~~ONDENSED~~C~~ONSOLIDATED~~F~~INANCIAL~~S~~TATEMENTS~~

~~(Unaudited)~~

~~Note 3 - Fair Value Measurement (Continued)~~

2021. 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. WeIn 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 ~~six~~three months ended ~~June 30,~~March 31, 2020.

In 2019, the Company entered an agreement with its equipment manufacturer granting the Company the option to purchase an additional 108,000 hydraulic horsepower ~~(“HHP”~~("HHP") of DuraStim® equipment, with the purchase option expiring at different times ~~through April 30, 2021.~~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, has been fully impaired and written off in the first quarter of 2020 because it iswas not probable that the Company will exercise the option to purchase the equipment given the 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~~three months ended ~~June 30,~~March 31, 2021 and 2020 ~~and 2019~~ in our hydraulic fracturing and drilling segments was $0 and $7.2 million, ~~and $0,~~ 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 0 additions to, or ~~disposal~~disposals of, goodwill during the ~~six~~three months ended ~~June 30, 2020 and 2019.~~March 31, 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 iswas fully ~~impaired. Accordingly, we recorded a goodwill impairment expense of $9.4 million~~impaired during the ~~six months ended June 30,~~first quarter of 2020. ~~There was 0 goodwill impairment expense during the three and six months ended June 30, 2019.~~

-7-

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 4 - Long-Term Debt

~~ABL~~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, 2020~~March 31, 2021 was approximately ~~$16.8 million.~~ $61.5 million. The ABL Credit Facility includes a Springing Fixed Charge Coverage Ratio to apply when excess availability is less than the greater of (i) 10% of the lesser of the facility size or the Borrowing Base or (ii) $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.

The loan origination costs relating to the ABL Credit Facility are classified as an asset in our balance sheet. ~~The weighted average interest rate for our~~There were 0 borrowings under the ABL Credit Facility ~~for the six months ended June 30, 2020 was 3.2%.~~

~~Total debt consisted~~as of ~~the following at June 30, 2020~~March 31, 2021 and December 31, ~~2019, respectively:~~2020.

~~PROPETRO HOLDING CORP.~~

N~~OTES~~TOC~~ONDENSED~~C~~ONSOLIDATED~~F~~INANCIAL~~S~~TATEMENTS~~

~~(Unaudited)~~

~~Note 4 - Long-Term Debt (Continued)~~

($ in thousands)
2020 2019
ABL Credit Facility $ —
$ 130,000
Total debt —
130,000
Less current portion of long-term debt —
—
Total long-term debt $ —
$ 130,000

Note 5 - Reportable Segment Information

The Company has 43 operating segments for which discrete financial information is readily available: hydraulic fracturing (inclusive of acidizing), cementing and coiled ~~tubing and drilling. In March 2020,~~ tubing.~~the Company shut down its flowback operating segment and subsequently disposed of the assets for approximately $1.6 million.~~ These operating segments represent how the Chief Operating Decision Maker evaluates performance and allocates resources.

In accordance with the FASB Accounting Standards Codification ~~("ASC"~~(“ASC”) 280—Segment Reporting, the Company has 1 reportable segment (pressure pumping) comprised of the hydraulic fracturing and cementing operating segments. ~~All other~~The coiled tubing operating ~~segments~~segment and corporate administrative expense (inclusive of our total income tax expense (benefit) and interest expense) are included in the ~~‘‘all other’’~~"all other" category in the table below. Total corporate administrative expense for the three ~~and six~~ months ended ~~June 30,~~March 31, 2021 and 2020 was ~~$10.6~~$5.0 million and ~~$20.9 million, respectively. The corporate administrative expense for the three and six months ended June 30, 2019 was $27.5 million and $57.2~~$10.3 million, respectively.

Our hydraulic fracturing operating segment revenue approximated ~~89.7%~~93.3% and ~~93.7%~~94.8% of our pressure pumping revenue during the three ~~and six~~ months ended ~~June 30,~~March 31, 2021 and 2020, ~~respectively. During the three and six months ended June 30, 2019, our hydraulic fracturing operating segment revenue approximated 95.6% and 95.8% 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):

~~PROPETRO HOLDING CORP.~~

N~~OTES~~TOC~~ONDENSED~~C~~ONSOLIDATED~~F~~INANCIAL~~S~~TATEMENTS~~

~~(Unaudited)~~

~~Note 5- Reportable Segment Information (Continued)~~

-8-

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 June 30, 2020 $ 1,052,915
$ 40,687
$ 1,093,602

Three Months Ended June 30, 2019
Pressure Pumping All Other Total
Service revenue $ 515,867
$ 13,627
$ 529,494
Adjusted EBITDA $ 131,187
$ (4,625 ) $ 126,562
Depreciation and amortization $ 34,023
$ 1,459
$ 35,482
Goodwill at December 31, 2019 $ 9,425
$ —
$ 9,425
Capital expenditures $ 156,542
$ 4,677
$ 161,219
Total assets at December 31, 2019 $ 1,381,811
$ 54,300
$ 1,436,111

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 June 30, 2020 $ 1,052,915
$ 40,687
$ 1,093,602

Six Months Ended June 30, 2019
Pressure Pumping All Other Total
Service revenue $ 1,047,931
$ 27,742
$ 1,075,673
Adjusted EBITDA $ 282,228
$ (5,391 ) $ 276,837
Depreciation and amortization $ 65,806
$ 2,793
$ 68,599
Goodwill at December 31, 2019 $ 9,425
$ —
$ 9,425
Capital expenditures $ 238,577
$ 8,789
$ 247,366
Total assets at December 31, 2019 $ 1,381,811
$ 54,300
$ 1,436,111

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 5- Reportable Segment Information (Continued)


	Three Months Ended March 31, 2021
	Pressure Pumping		All Other		Total
Service revenue	$	158,191	$	3,267	$	161,458
Adjusted EBITDA	$	31,870	$	(11,853)	$	20,017
Depreciation and amortization	$	32,513	$	965	$	33,478
Capital expenditures	$	30,023	$	2,305	$	32,328
Total assets at March 31, 2021	$	1,005,365	$	39,418	$	1,044,783

	Three Months Ended March 31, 2020
	Pressure Pumping		All Other		Total
Service revenue	$	386,919	$	8,150	$	395,069
Adjusted EBITDA	$	78,664	$	(3,741)	$	74,923
Depreciation and amortization	$	38,969	$	1,236	$	40,205
Capital expenditures	$	39,268	$	828	$	40,096
Total assets at December 31, 2020	$	1,009,631	$	41,108	$	1,050,739

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


	Three Months Ended March 31, 2021
	Pressure Pumping		All Other		Total
Net loss	$	(13,675)	$	(6,700)	$	(20,375)
Depreciation and amortization	32,513		965		33,478
Interest expense	0		176		176
Income tax benefit	0		(6,663)		(6,663)
Loss on disposal of assets	13,032		20		13,052
Stock-based compensation	0		2,487		2,487
Other income	0		(1,789)		(1,789)
Other general and administrative expense, (net)(1)	0		(961)		(961)
Severance expense	0		612		612
Adjusted EBITDA	$	31,870	$	(11,853)	$	20,017

	Three Months Ended March 31, 2020
	Pressure Pumping		All Other		Total
Net income (loss)	$	4,308	$	(12,112)	$	(7,804)
Depreciation and amortization	38,969		1,236		40,205
Impairment expense	15,559		1,095		16,654
Interest expense	1		1,280		1,281
Income tax expense	0		(909)		(909)
Loss on disposal of assets	19,815		39		19,854
Stock-based compensation	0		471		471
Other expense	0		3		3
Other general and administrative expense(1)	0		5,135		5,135
Retention bonus and severance expense	12		21		33
Adjusted EBITDA	$	78,664	$	(3,741)	$	74,923

(1)Other general and administrative expense, (net) 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.

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

Three Months Ended June 30, 2019
Pressure Pumping All Other Total
Net income (loss) $ 64,230
$ (28,097 ) $ 36,133
Depreciation and amortization 34,023
1,459
35,482
Interest expense 22
2,004
2,026
Income tax expense —
10,272
10,272
Loss on disposal of assets 31,117
81
31,198
Stock-based compensation —
2,840
2,840
Other expense —
276
276
Other general and administrative expense⁽¹⁾
—
6,540
6,540
Retention bonus expense 1,795
—
1,795
Adjusted EBITDA $ 131,187
$ (4,625 ) $ 126,562

~~PROPETRO HOLDING CORP.~~

N~~OTES~~TOC~~ONDENSED~~C~~ONSOLIDATED~~F~~INANCIAL~~S~~TATEMENTS~~

~~(Unaudited)~~-9-

~~Note 5- Reportable Segment Information (Continued)~~

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

Six Months Ended June 30, 2019
Pressure Pumping All Other Total
Net income (loss) $ 162,324
$ (56,386 ) $ 105,938
Depreciation and amortization 65,806
2,793
68,599
Interest expense 22
3,906
3,928
Income tax expense —
32,164
32,164
Loss on disposal of assets 50,123
302
50,425
Stock-based compensation —
4,669
4,669
Other expense —
464
464
Other general and administrative expense ⁽¹⁾
—
6,540
6,540
Deferred IPO and retention bonus expense $ 3,953
$ 157
$ 4,110
Adjusted EBITDA $ 282,228
$ (5,391 ) $ 276,837


~~(1)~~	Other general and administrative expense relates to nonrecurring professional fees paid to external consultants in connection with the Company's expanded audit committee review, SEC investigation and shareholders' litigation.

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 6 - Net ~~Income (Loss)~~Loss Per Share

Basic net ~~income (loss)~~loss per common share is computed by dividing the net ~~income (loss)~~loss relevant to the common stockholders by the weighted average number of common shares outstanding during the period. Diluted net ~~income (loss)~~loss per common share uses the same net ~~income (loss)~~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,~~March 31, 2021 and 2020, ~~and 2019,~~ (in thousands, except for per share data).

Three Months Ended June 30,
2020 2019
Numerator (both basic and diluted)
Net income (loss) relevant to common stockholders $ (25,920 ) $ 36,133

Denominator
Denominator for basic income (loss) per share 100,821
100,425
Dilutive effect of stock options —
3,294
Dilutive effect of performance share units —
449
Dilutive effect of restricted stock units —
211
Denominator for diluted income (loss) per share 100,821
104,379

Basic income (loss) per share $ (0.26 ) $ 0.36
Diluted income (loss) per share $ (0.26 ) $ 0.35

Six Months Ended June 30,
2020 2019
Numerator (both basic and diluted)
Net income (loss) relevant to common stockholders $ (33,724 ) $ 105,938

Denominator
Denominator for basic income (loss) per share 100,754
100,329
Dilutive effect of stock options —
3,252
Dilutive effect of performance share units —
418
Dilutive effect of restricted stock units —
182
Denominator for diluted income (loss) per share 100,754
104,181

Basic income (loss) per share $ (0.33 ) $ 1.06
Diluted income (loss) per share $ (0.33 ) $ 1.02


	Three Months Ended March 31,
	2021		2020
Numerator (both basic and diluted)
Net loss relevant to common stockholders	$	(20,375)	$	(7,804)

Denominator
Denominator for basic loss per share	101,550		100,687
Dilutive effect of stock options	0		0
Dilutive effect of performance share units	0		0
Dilutive effect of restricted stock units	0		0
Denominator for diluted loss per share	101,550		100,687

Basic loss per share	$	(0.20)	$	(0.08)
Diluted loss per share	$	(0.20)	$	(0.08)

~~PROPETRO HOLDING CORP.~~

N~~OTES~~TOC~~ONDENSED~~C~~ONSOLIDATED~~F~~INANCIAL~~S~~TATEMENTS~~

~~(Unaudited)~~

As shown in the table below, the following stock options, restricted stock units and performance stock units outstanding as of ~~June 30,~~March 31, 2021 and 2020, ~~and 2019,~~ respectively, have not been included in the calculation of diluted ~~income (loss)~~loss per common share for the three ~~and six~~ months ended ~~June 30,~~March 31, 2021 and 2020 ~~and 2019~~ because they will be anti-dilutive to the calculation of diluted net ~~income (loss)~~loss per common ~~share.~~share:

(In thousands)
2020 2019

Stock options 4,224
—
Restricted stock units 1,269
—
Performance stock units 1,051
—
Total 6,544
—


(In thousands)
	2021	2020
Stock options	1,912	4,230
Restricted stock units	1,564	1,228
Performance stock units	1,480	1,051
Total	4,956	6,509

Note 7 - Stock-Based Compensation

Stock Options

There were no0 new stock option grants during the ~~six~~three months ended ~~June 30, 2020.~~March 31, 2021. As of ~~June 30, 2020,~~March 31, 2021, the aggregate intrinsic value for our outstanding stock options was ~~$6.5~~$10.2 million, and the aggregate intrinsic value for our exercisable stock options was ~~$6.5~~$10.2 million. The aggregate intrinsic value for the exercised stock options during the three months ended March 31, 2021 was approximately $11.7 million. The remaining exercise period for both the outstanding and exercisable stock options as of ~~June 30, 2020,~~March 31, 2021 was 3.3 ~~years and 3.2 years, respectively.~~years.

-10-

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 7 - Stock-Based Compensation (Continued)

A summary of the stock option activity for the ~~six~~three months ended ~~June 30, 2020~~March 31, 2021 is presented ~~below.~~below:

Number of Shares Weighted
Average
Exercise
Price
Outstanding at January 1, 2020 4,300,088
$ 5.03
Granted —
$ —
Exercised —
$ —
Forfeited (70,960 ) $ 14.00
Expired (5,619 ) $ 14.00
Outstanding at June 30, 2020 4,223,509
$ 4.87
Exercisable at June 30, 2020 4,086,657
$ 4.57


	Number of Shares	Weighted Average Exercise Price
Outstanding at January 1, 2021	4,200,341	$	4.82
Granted	0	$	0
Exercised	(2,212,215)	$	3.33
Forfeited	0	$	14.00
Expired	(76,306)	$	14.00
Outstanding at March 31, 2021	1,911,820	$	6.18
Exercisable at March 31, 2021	1,911,820	$	6.18

Restricted Stock Units

During the ~~six~~three months ended ~~June 30, 2020,~~March 31, 2021, we granted a total of ~~1,143,230~~700,865 restricted stock units ("RSUs") to employees, officers and directors pursuant to the ProPetro Holding Corp. ~~2017~~2020 Long Term Incentive ~~Award~~ Plan (the ~~"Incentive~~"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 1 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, 2020,~~March 31, 2021, the total unrecognized compensation expense for all RSUs was approximately ~~$9.3~~$10.5 million, and is expected to be recognized over a weighted average period of approximately ~~2.2 years.~~

~~PROPETRO HOLDING CORP.~~

N~~OTES~~ 2.4 years.TOC~~ONDENSED~~C~~ONSOLIDATED~~F~~INANCIAL~~S~~TATEMENTS~~

~~(Unaudited)~~

~~Note 7 - Stock-Based Compensation (Continued)~~

The following table summarizes RSUs activity during the ~~six~~three months ended ~~June 30, 2020:~~March 31, 2021:

Number of
Shares Weighted
Average
Grant Date
Fair Value
Outstanding at January 1, 2020 613,217
$ 18.75
Granted 1,143,230
$ 7.05
Vested (202,493 ) $ 18.22
Forfeited (285,157 ) $ 15.91
Canceled —
$ —
Outstanding at June 30, 2020 1,268,797
$ 8.93


	Number of Shares	Weighted Average Grant Date FV
Outstanding at January 1, 2021	1,165,369	$	8.50
Granted	700,865	$	9.77
Vested	(301,830)	$	9.74
Forfeited	0	$	0
Canceled	0	$	0
Outstanding at March 31, 2021	1,564,404	$	8.83

Performance Share Units

During the ~~six~~three months ended ~~June 30, 2020,~~March 31, 2021, we granted ~~966,242~~544,699 performance share units ("PSUs") ~~(excluding PSUs that were administratively cancelled and regranted)~~ 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, 2020:~~

Period
Granted Target Shares
Outstanding at January 1,
2020 Target
Shares
Granted Target Shares Vested Target
Shares
Forfeited Target Shares Outstanding at June 30, 2020 Weighted
Average
Grant Date
Fair Value per
Share
2017 151,492
—
(151,492 ) —
—
$ 10.73
2018 156,576
—
—
(72,254 ) 84,322
$ 27.51
2019 214,553
—
—
(88,235 ) 126,318
$ 34.82
2020 —
966,242

(125,391 ) 840,851
$ 9.42
Total 522,621
966,242
(151,492 ) (285,880 ) 1,051,491
$ 13.92

The total stock-based compensation expense for the six months ended June 30, 2020 and 2019 for all stock awards was $3.4 million and $1.8 million, respectively. The total unrecognized stock-based compensation expense as of June 30, 2020 was approximately $18.3 million, and is expected to be recognized over a weighted average period of approximately 2.1 years.

-11-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 7 - Stock-Based Compensation (Continued)

The following table summarizes information about PSUs activity during the three months ended March 31, 2021:


Period Granted	Target Shares Outstanding at January 1, 2021		Target Shares Granted		Target Shares Vested		Target Shares Forfeited		Target Shares Outstanding at March 31, 2021		Weighted Average Grant Date FV per Share
2017	0		0		0		0		0		$	10.73
2018	84,322		0		(84,322)		0		0		$	27.51
2019	126,318		0		0		0		126,318		$	27.49
2020	808,638		0		0		0		808,638		$	8.30
2021	0		544,699		0		0		544,699		$	15.35
Total	1,019,278		544,699		(84,322)		0		1,479,655		$	12.53

Weighted Average FV Per Share	$	12.27	$	15.35	$	27.51	$	0	$	12.53

The total stock-based compensation expense for the three months ended March 31, 2021 and 2020 for all stock awards was $2.5 million and $0.5 million, respectively. The total unrecognized stock-based compensation expense as of March 31, 2021 was approximately $22.9 million, and is expected to be recognized over a weighted average period of approximately 2.4 years.

Note 8 - Related-Party Transactions

Corporate Office Building

~~The~~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. The rent expense incurred on our corporate office building is~~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 5 yards from an entity, in which certain former executive officers ~~an executive officer~~ and a director of the Company have equity interests and the total annual rent expense for each of the ~~five~~5 yards was approximately $0.03 million, $0.03 million, $0.1 million, $0.1 million, and $0.2 million, respectively. The Company also leased aits drilling yard from another entity, in which a certain ~~executive officer of the Company has an equity interest, and with annual lease expense of approximately $0.1 million.~~

~~Transportation and Equipment Rental~~

~~For the six months ended June 30, 2019, the Company incurred costs for transportation services with an entity, in which a~~ former executive officer of the Company has an equity interest, ~~of approximately $0.2 million. NaN transportation services were provided by the related party during the six months ended June 30, 2020.~~

~~The Company also rented equipment in Elk City, Oklahoma~~ for ~~our flowback operations from~~ an ~~entity, which a former executive officer of the Company has an equity interest. During the six months ended June 30, 2019, the Company incurred equipment rental costs~~annual lease expense of approximately $0.1 million. ~~This rental arrangement was~~In November 2020, we terminated ~~in January 2020.~~the drilling yard lease.

Equipment Rental and Other Services

The Company obtains equipment maintenance ~~and repair~~ services from an entity that has a family relationship with an executive officer of the Company. During the ~~six~~three months ended ~~June 30,~~March 31, 2021 and 2020, the Company incurred approximately $0 and $0.3 million, respectively, for equipment maintenance ~~and repair~~ services associated with this related party.

At ~~June 30, 2020~~March 31, 2021 and December 31, ~~2019,~~2020, the Company had 0 outstanding payables ~~in connection with transactions~~or receivables to or from the above related ~~parties.~~party transactions.

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. In July 2019, we terminated our crew camp facility lease entered into with Pioneer in connection with the Pioneer Pressure Pumping Acquisition, and the total crew camp facility lease payments to Pioneer in 2019 were approximately $0.1 million.

Revenue from services provided to Pioneer (including idle fees) accounted for ~~approximately $64.3~~approximately $86.3 million and ~~$127.0~~$127.4 million of our total revenue during the three months ended ~~June 30,~~March 31, 2021 and 2020, ~~and 2019,~~ respectively. Revenue from services provided to Pioneer (including idle fees) accounted for approximately $191.6 million and $287.1 million of our total revenue during the six months ended June 30, 2020 and 2019, 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 three months ended June 30, 2020 and 2019, the Company reimbursed Pioneer approximately $0.1 million and $1.3 million, respectively. During the six months ended June 30, 2020 and 2019, the Company reimbursed Pioneer approximately $2.7 million and $1.3 million, respectively.

As of June 30, 2020, the total accounts receivable due from Pioneer, including estimated unbilled receivable for services (including idle fees) we provided, amounted to approximately $47.2 million and the amount due to Pioneer was $0. As of December 31, 2019, the balance due from Pioneer for services (including idle fees) we provided and billed amounted to approximately $61.7 million and the amount due to Pioneer was $0.

-12-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 8 - Related-Party Transactions (Continued)

In connection with the Pioneer Pressure Pumping Acquisition, the Company agreed to reimburse Pioneer for the Company's portion of the retention bonuses paid to former Pioneer employees that were subsequently employed by the Company. During the three months ended March 31, 2021 and 2020, the Company fully reimbursed Pioneer approximately $0 and $2.6 million, respectively.

As of March 31, 2021, the total accounts receivable due from Pioneer, including estimated unbilled receivable for services (including idle fees) we provided, amounted to approximately $61.2 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.

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~~three months ended ~~June 30,~~March 31, 2021 and 2020, ~~and 2019,~~ the Company made lease payments of approximately ~~$0.2~~ $0.1 million and ~~$0.2~~$0.1 million, respectively. The assets and liabilities under this contract are equally allocated between our cementing and coiled tubing segments. In addition to the contractual lease period, the contract includes an optional renewal of up to ten years, and in management's judgment the exercise of the renewal option is not reasonably assured. The contract does not include a residual value guarantee, covenants or financial restrictions. Further, the Real Estate Lease does not contain variability in payments resulting from either an index change or rate change. Effective January 1, 2019, the remaining lease term in our present value estimate of the minimum future lease payments was four years.

Consistent with the requirements of the new lease standard, ASC 842, we have determined the 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, 2020,~~March 31, 2021, the weighted average discount rate and remaining lease term was 6.7% and ~~2.8~~2.0 years, respectively.

As of ~~June 30, 2020,~~March 31, 2021, our total operating lease right-of-use asset cost was approximately $1.2 million, and accumulated amortization was approximately ~~$0.4 million.~~$0.6 million. For the ~~six~~three months ended ~~June 30,~~March 31, 2021 and 2020, ~~and 2019,~~ we recorded operating lease cost of approximately ~~$0.2~~ $0.1 million and ~~$0.3~~$0.1 million, respectively, in our statement of operations.

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. The Ground Lease did not include any residual value guarantee, covenants or financial restrictions. Further, the Ground Lease did not contain variability in payments resulting from either an index change or rate change. In March 2020, the Company exercised its option and purchased the land associated with the Ground Lease for approximately $2.5 million. ~~For the six months ended June 30, 2020 and 2019, the interest on our finance lease was approximately $0 and $0.1 million, respectively.~~

~~The maturity analysis of liabilities and reconciliation to undiscounted and discounted remaining future lease payments for our operating lease as of June 30, 2020 are as follows:~~

($ in thousands)
2020 $ 184
2021 377
2022 389
2023 98
2024 —
Total undiscounted future lease payments 1,048
Less: amount representing interest (95 )
Present value of future lease payments (lease obligation) $ 953

The total cash paid for amounts included in the measurement of our operating and finance lease liabilities during the six months ended June 30, 2020 was approximately $0.2 million and $0.03 million, respectively. During the six months ended June 30, 2019, total cash paid for amounts included in the measurement of our operating and finance lease liabilities was approximately $0.3 million and $0.2 million, respectively.

-13-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 9 - Leases (Continued)

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 March 31, 2021 are as follows:



($ in thousands)
2021	$	285
2022	389
2023	98
2024	0
Total undiscounted future lease payments	$	772
Less: amount representing interest	(52)
Present value of future lease payments (lease obligation)	$	720

The total cash paid for amounts included in the measurement of our operating lease liability during the three months ended March 31, 2021 was approximately $0.1 million. During the three months ended March 31, 2020, total cash paid for amounts included in the measurement of our operating and finance lease liabilities was approximately $0.1 million and $0.03 million, respectively.

We elected the practical expedient, consistent with ASC 842, to exclude leases with an initial term of twelve months or less ("short-term leases") from our balance sheet and continue to record short-term leases as a period expense. For the ~~six~~three months ended ~~June 30,~~March 31, 2021 and 2020 our short-term ~~leases and lodging~~lease expense was approximately ~~$0.6~~ $0.2 million ~~and $1.7 million, respectively. During the six months ended June 30, 2019, our short-term leases and lodging expense was approximately~~and $0.3 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 ~~$2.2 million, respectively. At June 30, 2020,~~future lease income, which will be ratably recognized over the ~~total remaining~~ lease ~~commitments for all of our short-term leases and lodging commitments was~~period, is approximately ~~$6.0~~$3.0 million.

Note 10 - Commitments and Contingencies

As of ~~June 30, 2020, the Company has an existing agreement with its equipment manufacturer granting the Company the option to purchase additional 108,000 HHP of~~ ~~DuraStim®~~ equipment, with the purchase option expiring at different times through April 30, 2021. The option fee of $6.1 million, which was classified as a deposit for property and equipment when the agreement was entered into in 2019, has been impaired and written off as of June 30, 2020 as it is not probable that we will exercise our option to purchase the equipment given the current market conditions and the depressed oil and gas industry.

~~As of June 30, 2020,~~March 31, 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 $3.0 million. At March 31, 2021, the total remaining commitments, in connection with the lodging arrangement for our crews was approximately ~~$0.8 million.~~ $5.5 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, ~~constituting substantially all~~based primarily on a certain percentage of ~~its~~our sand requirements from ~~the Sand suppliers,~~our customers or in certain situations based on predetermined fixed minimum volumes, otherwise certain penalties (shortfall fees) may be charged. ~~Under certain of the purchase agreements, a shortfall fee applies if the Company purchases less than the minimum volume of sand.~~ The shortfall fee represents liquidated damages and is ~~either a fixed percentage of the purchase price for the minimum volumes or~~based on a fixed price per ton of unpurchased volumes. Under one of the purchase agreements, the Company is obligated to purchase a specified percentage of its overall sand requirements, or it must pay the supplier the difference between the purchase price of the minimum volumes under the purchase agreement and the purchase price of the volumes actually purchased. Our minimum volume commitments under the purchase agreements are either based on a percentage of our total usage or fixed minimum quantity. Our agreements with the Sand suppliers expire at different times prior to ~~April 30, 2022. During~~December 31, 2025. During the ~~six~~three months ended ~~June 30,~~March 31, 2021 and 2020, ~~and 2019,~~ no shortfall fee ~~has been~~was recorded. 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 ~~(“LandCo”)~~ 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 and during the six months ended June 30, 2019 was approximately $22.1~~ million.

As of ~~June 30, 2020,~~March 31, 2021, the Company had issued letters of credit of approximately $3.7 million under the ~~Company's~~ ABL Credit Facility ~~relating to~~in connection with the Company’s casualty insurance policy.

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 10 - Commitments and Contingencies (Continued)

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, ~~in the Logan Lawsuit,~~ 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.

~~PROPETRO HOLDING CORP.~~

N~~OTES~~TOC~~ONDENSED~~C~~ONSOLIDATED~~F~~INANCIAL~~S~~TATEMENTS~~

~~(Unaudited)~~

~~Note 10 - Commitments and Contingencies (Continued)~~

In ~~January~~August 2020, ~~Boca Raton Firefighters’ and Police Pension Fund (“Boca Raton”)~~the Company filed a ~~shareholder derivative suit~~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.

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

In ~~April~~October 2020, Jye-Chun Chang filed a shareholder derivative suit in the U.S. District Court for the Western District of Texas (the “Chang Lawsuit”) against certain of the Company’s current and former officers and directors (the “Chang Defendants”). The Company was named as a nominal defendant only. The claims include (i) violations of Section 14(a) of the Exchange Act, (ii) breach of fiduciary duties, (iii) unjust enrichment, (iv) abuse of control, (v) gross mismanagement and (vi) waste of corporate assets. Chang did not quantify any alleged damages in its complaint but, in addition to attorneys’ fees and costs, Chang seeks various forms of relief, including (i) declaring that Chang may sustain the action on behalf of the Company ~~(ii) declaring that the Chang Defendants breached their fiduciary duties~~and other defendants filed motions to the Company, (iii) damages sustained by the Company as a result of the Chang Defendants’ alleged misconduct, (iv) equitable relief in the form of improvements to the Company’s governance and controls and (v) restitution.

In May 2020, the U.S. District Court for the Western District of Texas consolidated the Boca Raton and Chang Lawsuits and named Boca Raton the Lead Plaintiff (the "Shareholder Derivative Lawsuit"). Plaintiffs indismiss the Shareholder Derivative Lawsuit ~~have yet~~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 ~~file an amended consolidated complaint.~~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~~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, 2020,~~March 31, 2021, no provision was made by the Company in connection with these pending lawsuits and the SEC investigation as ~~they are still at early stages and~~ the final ~~outcomes~~outcome cannot be reasonably estimated.

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 2019, the Texas Comptroller of Public Accounts commenced a routine audit of the Company's gross receipts and sales, excise and use taxes for the periods of July 2015 through December 2018. As of June 30, 2020, although the audit has not been finalized, we do not believe that any material tax liability will arise from the audit.

-15-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1110 - ~~Subsequent Events~~Commitments and Contingencies (Continued)

~~Delinquent SEC Filings~~

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 ~~July 2,~~December 31, 2020, the ~~Company has filed all its delinquent SEC filings prior~~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 ~~expiration of~~Company from the ~~additional trading period granted by the New York Stock Exchange (the "NYSE"),~~sales and excise and use tax audit was approximately $2.1 million, which was ~~set to expire on July 15, 2020. Effective July 2, 2020,~~recorded as part of other income in our statement of operations during the ~~Company became current in its filing obligations with the SEC and regained compliance with the NYSE's continued listing standards.~~three months ended March 31, 2021.

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.

We are a ~~growth-oriented,~~ 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 ~~currently~~ one of the largest providers of hydraulic fracturing services in the region by hydraulic horsepower ("HHP").

Our total available HHP as of ~~June 30, 2020~~March 31, 2021 was ~~1,469,000~~1,388,000 HHP, which was comprised of ~~1,415,000~~15,000 HHP of our new Tier IV Dynamic Gas Blending ("DGB") equipment, 1,265,000 HHP of conventional ~~HHP~~Tier II equipment and ~~54,000~~108,000 HHP of ~~the~~our new DuraStim® hydraulic fracturing equipment. WeDuring the second quarter of 2021, we expect to ~~receive~~take delivery of our remaining ~~54,000~~committed 35,000 HHP of new DGB equipment. On average, a fleet consists of approximately 50,000 HHP but could vary significantly depending on the ~~newly built~~job design and ~~fully paid~~customer demand at the wellsite. With the industry transition to lower emissions equipment and simultaneous 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 back up HHP at the wellsites based on our customers' and operational needs or as we retire and replace conventional Tier II equipment.

In 2019, we entered into a purchase commitment for 108,000 HHP of DuraStim®electric powered hydraulic fracturing equipment. Our DuraStim® equipment is still being tested and has only been deployed to our customers' wellsites on a limited scale. As we continue with our testing of the equipment, the 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 has set a goal to commercialize its first DuraStim® fleet to our customer wellsites in the second half of 2021. We also have an option to purchase up to an additional 108,000 HHP of DuraStim® hydraulic fracturing equipment in ~~2021.~~the future through July 31, 2022. We currently have gas turbines, to 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, customers or a third-party supplier.

Our competitors include many large and small oilfield services companies, including ~~RPC, Inc.,~~ Halliburton Company, ~~Patterson-UTI Energy~~Liberty Oilfield Services Inc., Nextier Oilfield Solutions Inc., ~~Liberty Oilfield Services~~Patterson-UTI Energy Inc., ~~Superior Energy Services~~RPC, Inc., ~~Schlumberger Limited,~~ FTS International Inc. and a number of private ~~companies.~~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,~~provider. However, we have recently observed the energy industry and our customers shift to lower emissions equipment, which we believe ~~that other~~will be an increasingly important ~~factors include operational efficiency, technical expertise,~~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 requirement, and ~~equipment quality, and health and safety standards.~~the depressed energy industry. While we seek to price our services competitively, we believe many of our customers elect to work with us based on our ~~deep local roots,~~ operational ~~expertise,~~efficiencies, productivity, equipment quality, commitment to safety and the ~~capability~~ability of our ~~modern fleet~~people to handle the most complex Permian Basin well ~~completions, and commitment to safety and reliability.~~completions.

Our substantial market presence in the Permian Basin positions us well to capitalize on drilling and completion activity in the region. ~~Historically,~~Primarily, our operational focus has been in the Permian Basin's Midland sub-basin, where our customers have ~~primarily~~ operated. However, aswe are well positioned to increase our activity ~~in the Delaware sub-basin increased, we expanded our presence~~ in the Delaware sub-basin in response to demand from our customers. ~~Given our dedicated relationships with a variety of Delaware sub-basin operators, we believe that we are uniquely positioned to capture large addressable growth opportunity as the basin develops.~~ 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 ~~modern~~ hydraulic fracturing fleet has been designed to handle Permian 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. ~~The majority of our fleet has been delivered in recent years, and we continue to fully maintain our equipment to ensure optimal performance and reliability.~~

In addition to our core pressure pumping segment operations, which includes our cementing operations, we also offer ~~a suite of complementary well completion and production services, including~~ coiled tubing ~~and other~~ services. We believe ~~these complementary~~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, 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 ~~is anticipated to~~could continue to have an adverse effect on global economic activity for the immediate future, ~~and~~ has resulted in travel ~~restrictions,~~limitations, business closures and the institution of quarantining and other restrictions on movement and business operations in many communities. ~~The~~With the slowdown in global economic activity attributable to COVID-19 ~~has resulted~~beginning in early 2020, the energy industry experienced a dramatic decline in the demand for energy and crude oil prices, which ~~directly impacts~~impacted our industry and the Company. In addition, global crude oil prices ~~experienced a collapse starting~~have been highly volatile especially in ~~early March~~ 2020 ~~as a direct result of failed negotiations between OPEC and Russia. In response~~with the overall global uncertainty related to ~~the global economic slowdown, OPEC had recommended a decrease in~~anticipated production levels in order to accommodate reduced demand. Russia rejected the recommendation of OPEC as a concession to U.S. producers. After the failure to reach an agreement, Saudi Arabia, a dominant member of OPEC, and other Persian Gulf OPEC members announced intentions to increase production and offer price discounts to buyers in certain geographic regions.

As the breadth of the COVID-19 health crisis expanded throughout the month of March 2020 and governmental authorities implemented more restrictive measures to limit person-to-person contact, global economic activity continued to decline commensurately. The associated impact on the energy industry has been adverse and continued to be exacerbated by the unresolved conflict regarding production. In the second week of April 2020, OPEC reconvened to discuss the matter of production cuts in light of unprecedented disruption and supply and demand imbalances that expanded since the failed negotiations in early March 2020. Tentative agreements were reached to cut production by up to 10 million barrels of oil per day, or BOPD, with allocations to be made among thefor OPEC+ participants ~~which began to take effect in~~and the ~~first half~~impact of ~~May 2020. However, in July~~COVID-19 pandemic.

In 2020, OPEC+ agreed to increase production from such reduced levels, beginning in August 2020. In addition, commodity prices remain depressed as a result of an increasingly utilized global storage network and near-term demand loss attributable to the ~~COVID-19 health crisis and related economic slowdown.~~

~~The~~ combined effect of COVID-19 and the energy industry disruptions led to a significant decline in WTI crude oil prices ofto approximately ~~67 percent from the beginning of January 2020, when prices were approximately $62~~$21 per barrel ~~through~~at the end of March ~~2020, when they were just above $20 per barrel. Overall~~2020. 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 gradual recovery in the energy industry and overall economic activities from its lowest point in 2020. However, there is still some level of uncertainty in the global market resulting from the COVID-19 pandemic and the risk of an outbreak of a new virus, which could result in continued depressed global energy demand and declining crude oil ~~price volatility has continued despite apparent agreement among OPEC+ regarding production cuts and as~~prices. As of ~~July 31, 2020,~~May 3, 2021, the WTI price for a barrel of crude oil was approximately ~~$41.~~$65.

Despite a significant decline in drilling and completion activity by U.S. producers starting in mid-March 2020, domestic supply continues to exceed demand which has led to significant operational stress with respect to capacity limitations associated with storage, pipeline and refining infrastructure, particularly within the Gulf Coast region. The combined effect In light of the ~~aforementioned factors is anticipated to have a continuing adverse impact on~~COVID-19 pandemic and the energy industry ~~in general and our operations specifically.~~

~~The~~disruptions, the Permian Basin rig count ~~has~~ decreased significantly from approximately 403 at the beginning of January 2020 to approximately ~~125 in July~~175 at the end of December 2020, according to Baker ~~Hughes,~~Hughes. However, the rig count slowly increased exiting 2020 and ~~may continue to decline if current~~is currently at 224 rigs at the end of March 2021. If the rig count and market conditions do not ~~improve. As a result of the depressed market conditions and events,~~continue to improve, the Company expects a material adverse impact on the services we provide resulting from our customers shutting down completions of wells and pricing pressure from our customers to reduce the prices of our services. We expect the reduction in the number of wells completion activities and the pricing pressure from our customers to have a negative impact on our future revenue,its business, results of operations and cash ~~flows.~~flows, resulting from a decrease in our customer activity and pricing pressure from its customers.

Government regulations and investors are demanding the oil and gas industry transition to a lower emissions operating environment, including the E&P 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.

Although the oil and gas market has not fully recovered and pricing for our services is ~~currently~~still depressed, 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. If the ~~market rebounds,~~oil and gas industry recovers, we believe there will be increased demand for pressure pumping services in the Permian ~~Basin where we operate.~~Basin. If ~~the current depressed oil prices and economic~~market conditions remain depressed for a longer period of time, our profitability and future cash flows will be negatively impacted, and as a result, we may be required to record additional asset impairment charges in future periods.

Our results of operations have historically reflected seasonal tendencies, typically in the fourth quarter, relating to holiday seasons, inclement winter weather and exhaustion of our customers' annual budgets. As a result, we typically experience declines in our operating results in November and December, even in a stable commodity price and operations environment. The seasonal tendencies and the current depressed oil and gas market conditions could result in a longer recovery time in the oil and gas industry thereby significantly impacting on revenue, results of operations and cash flows for a longer period of time beyond 2020.

Actions to Address the Economic Impact of COVID-19 and ~~Decline in Commodity Prices~~Depressed Energy Industry

~~Since March 2020, we~~We initiated several actions to mitigate the anticipated adverse economic conditions for the immediate future and to support our future financial position, liquidity and ~~the efficient continuity of our~~ operations as follows:

~~Growth Capital. We cancelled substantially all our planned growth capital expenditures for the remainder of 2020.~~

◦Capital Expenditures: our 2021 capital expenditures will be driven by customer activity levels and demand for our pressure pumping services. Our objective is to remain capital disciplined.

~~Other Expenditures.~~ ~~We significantly reduced our maintenance expenditures and field level consumable costs due to our reduced~~

◦Other Expenditures: we will continue to seek competitive pricing and cost saving measures for our expendable items, logistics, materials used in day-to-day operations and our large component replacement parts.

◦Labor Force: we will continue to make appropriate adjustments to our workforce to reflect outlook related to our customers' activity levels. We have been seeking lower pricing for our expendable items, materials used in day-to-day operations and large component replacement parts. Also, we have been internalizing certain support services that were outsourced.

~~Labor Force Reductions.~~ We have reduced our workforce by over 60% between April and May 2020, due to the changing activity levels for our services. We will continue to make appropriate adjustments to our workforce to reflect outlook related to activity levels.

~~Compensation Related Costs.~~ The directors and officers have voluntarily reduced compensation at different levels up to 20%. We have taken efforts to manage work schedules, primarily related to hourly employees, to minimize overtime costs.

~~Working Capital. We have negotiated more favorable payment terms with certain of our larger vendors and are continuing to increase our diligence in collecting and managing our portfolio of accounts receivables.~~

~~We are continuing to evaluate and consider additional cost saving measures.~~ We will continue to explore strategic options to improve our customers' efficiencies and prioritize safe operations, while maintaining the ~~safety and welfare~~most efficient headcount.

◦Working Capital: we will continue to monitor our payment terms with certain of our ~~employees~~larger vendors and ~~customers through these turbulent times.~~continue to increase our diligence in collecting and managing our portfolio of accounts receivables.

How We Evaluate Our Operations

Our management uses ~~a variety of financial metrics,~~ 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) ~~loss/(gain) on extinguishment of debt, (iii)~~ stock-based compensation, and ~~(iv)~~(iii) other unusual or ~~non‑recurring~~nonrecurring (income)/expenses, such as impairment charges, severance ~~costs~~and related ~~to our initial public offering and~~costs, costs related to asset acquisitions orand one-time professional fees. 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.

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


	Three Months Ended March 31, 2021
	Pressure Pumping		All Other		Total
Net loss	$	(13,675)	$	(6,700)	$	(20,375)
Depreciation and amortization	32,513		965		33,478
Interest expense	—		176		176
Income tax benefit	—		(6,663)		(6,663)
Loss on disposal of assets	13,032		20		13,052
Stock-based compensation	—		2,487		2,487
Other income	—		(1,789)		(1,789)
Other general and administrative expense, (net)(1)	—		(961)		(961)
Severance expense	—		612		612
Adjusted EBITDA	$	31,870	$	(11,853)	$	20,017

	Three Months Ended March 31, 2020
	Pressure Pumping		All Other		Total
Net income (loss)	$	4,308	$	(12,112)	$	(7,804)
Depreciation and amortization	38,969		1,236		40,205
Impairment expense	15,559		1,095		16,654
Interest expense	1		1,280		1,281
Income tax expense	—		(909)		(909)
Loss on disposal of assets	19,815		39		19,854
Stock-based compensation	—		471		471
Other expense	—		3		3
Other general and administrative expense(1)	—		5,135		5,135
Retention bonus and severance expense	12		21		33
Adjusted EBITDA	$	78,664	$	(3,741)	$	74,923

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
Impairment expense —
—
—
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

Three Months Ended June 30, 2019
Pressure Pumping All Other Total
Net income (loss) $ 64,230
$ (28,097 ) $ 36,133
Depreciation and amortization 34,023
1,459
35,482
Interest expense 22
2,004
2,026
Income tax expense —
10,272
10,272
Loss on disposal of assets 31,117
81
31,198
Stock-based compensation —
2,840
2,840
Other expense —
276
276
Other general and administrative expense⁽¹⁾
—
6,540
6,540
Retention bonus expense 1,795
—
1,795
Adjusted EBITDA $ 131,187
$ (4,625 ) $ 126,562

Results of Operations

We ~~conducted~~conduct our business through ~~four~~three operating segments: hydraulic fracturing, cementing and coiled ~~tubing, and drilling. Our drilling assets in our drilling operating segment have been idled since 2016.~~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 ~~All other~~ operating ~~segments~~segment and corporate administrative expenses (inclusive of our total income tax expense (benefit) and interest expense) are included in the ‘‘all other’’ category. Total corporate administrative expense for the three ~~and six~~ months ended ~~June 30,~~March 31, 2021 and 2020 was ~~$10.6~~ $5.0 million and ~~$20.9 million, respectively. The corporate administrative expense for the three and six months ended June 30, 2019 was $27.5 million and $57.2~~$10.3 million, respectively.

Our hydraulic fracturing operating segment revenue ~~approximated 89.7%~~approximated 93.3% and ~~93.7%~~94.8% of our pressure pumping revenue during the three ~~and six~~ months ended ~~June 30,~~March 31, 2021 and 2020, ~~respectively. During the three and six months ended June 30, 2019, our hydraulic fracturing operating segment revenue approximated 95.6% and 95.8% of our pressure pumping revenue,~~ respectively.

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


(in thousands, except for percentages)	Three Months Ended March 31,						Change Increase (Decrease)
	2021			2020			$			%
Revenue	$	161,458		$	395,069		$	(233,611)		(59.1)	%
Less (Add):
Cost of services (1)	123,378			300,848			(177,470)			(59.0)	%
General and administrative expense (2)	20,201			24,937			(4,736)			(19.0)	%
Depreciation and amortization	33,478			40,205			(6,727)			(16.7)	%
Impairment Expense	—			16,654			(16,654)			(100.0)	%
Loss on disposal of assets	13,052			19,854			(6,802)			(34.3)	%
Interest expense	176			1,281			(1,105)			(86.3)	%
Other (income) expense	(1,789)			3			(1,792)			(59,733.3)	%
Income tax benefit	(6,663)			(909)			(5,754)			633.0	%
Net loss	$	(20,375)		$	(7,804)		$	(12,571)		161.1	%

Adjusted EBITDA (3)	$	20,017		$	74,923		$	(54,906)		(73.3)	%
Adjusted EBITDA Margin (3)	12.4		%	19.0		%	(6.6)		%	(34.7)	%

Pressure pumping segment results of operations:
Revenue	$	158,191		$	386,919		$	(228,728)		(59.1)	%
Cost of services	$	119,768		$	294,224		$	(174,456)		(59.3)	%
Adjusted EBITDA (3)	$	31,870		$	78,664		$	(46,794)		(59.5)	%
Adjusted EBITDA Margin (4)	20.1		%	20.3		%	(0.2)		%	(1.0)	%

(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 $4.3 million and $1.5 million for the three months ended March 31, 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.

(in thousands, except for percentages)
Three Months Ended June 30, Change

2020 2019 Variance %
Revenue $ 106,109
$ 529,494
$ (423,385 ) (80.0 )%
Cost of services ⁽¹⁾
68,193
386,218
(318,025 ) (82.3 )%
General and administrative expense ⁽²⁾
20,331
27,889
(7,558 ) (27.1 )%
Depreciation and amortization 40,173
35,482
4,691
13.2 %
Loss on disposal of assets 8,734
31,198
(22,464 ) (72.0 )%
Interest expense 791
2,026
(1,235 ) (61.0 )%
Other expense 267
276
(9 ) (3.3 )%
Income tax expense (benefit) (6,460 ) 10,272
(16,732 ) (162.9 )%
Net income (loss) $ (25,920 ) $ 36,133
$ (62,053 ) (171.7 )%

Adjusted EBITDA ⁽³⁾
$ 25,410
$ 126,562
$ (101,152 ) (79.9 )%
Adjusted EBITDA Margin ⁽³⁾
23.9 % 23.9 % — % — %

Pressure pumping segment results of operations:
Revenue $ 103,815
$ 515,867
$ (412,052 ) (79.9 )%
Cost of services $ 65,991
$ 374,653
$ (308,662 ) (82.4 )%
Adjusted EBITDA ⁽³⁾
$ 34,030
$ 131,187
$ (97,157 ) (74.1 )%
Adjusted EBITDA Margin ⁽⁴⁾
32.8 % 25.4 % 7.4 % 29.1 %

Three Months Ended ~~June 30, 2020~~March 31, 2021 Compared to the Three Months Ended ~~June 30, 2019~~March 31, 2020

~~Revenues.~~Revenue. ~~Revenues~~Revenue decreased ~~80.0%~~59.1%, or ~~$423.4~~$233.6 million, to ~~$106.1~~$161.5 million during the three months ended ~~June 30, 2020,~~March 31, 2021, as compared to ~~$529.5~~$395.1 million during the three months ended ~~June 30, 2019.~~March 31, 2020. Our pressure pumping segment revenues decreased ~~79.9%~~59.1%, or ~~$412.1~~$228.7 million, for the three months ended ~~June 30, 2020,~~March 31, 2021, as compared to the three months ended ~~June 30, 2019.~~March 31, 2020. The decreases were primarily attributable to the significant decrease in demand for pressure pumping services, ~~that led to a significant decrease in our hydraulic fracturing fleet utilization,~~ as well as pricing discounts we provided to our customers following the depressed oil prices and slowdown in economic activity resulting from the COVID-19 pandemic. The decrease in demand for our pressure pumping services resulted in a significant decrease in our average effectively utilized fleet count to approximately 10.3 active fleets during the three months ended March 31, 2021 from approximately 18.6 active fleets for the three months ended March 31, 2020. In addition, our revenue for the three months ended March 31, 2021 was negatively impacted by the severe weather conditions experienced in February 2021, resulting in approximately eight days of lost revenue. Included in our revenue for the three months ended ~~June 30,~~March 31, 2021 and 2020 was revenue generated from idle fees charged to our customer of approximately $32.6 million. Our average active fleet count decreased to approximately 4.0 active fleets during the three months ended June 30, 2020 from approximately 25.6 active fleets for the three months ended June 30, 2019.$4.3 million and $1.5 million, respectively.

Revenues from services other than pressure pumping decreased ~~83.2%~~59.9%, or ~~$11.3~~$4.9 million, to ~~$2.3~~$3.3 million for the three months ended ~~June 30, 2020,~~March 31, 2021, as compared ~~$13.6~~to $8.2 million for the three months ended ~~June 30, 2019.~~March 31, 2020. The decrease in revenue from services other than pressure pumping was primarily attributable to the significant reduction in utilization experienced by our coiled tubing operations, which was driven by lower E&P completions activity following the depressed oil prices and impact of the COVID-19 ~~pandemic.~~pandemic, and the shutdown of our flowback operations.

Cost of Services. Cost of services decreased ~~82.3%~~59.0%, or ~~$318.0~~$177.5 million, to ~~$68.2~~$123.4 million for the three months ended ~~June 30, 2020,~~March 31, 2021, as compared to ~~$386.2~~$300.8 million during the three months ended ~~June 30, 2019.~~March 31, 2020. Cost of services in our pressure pumping segment decreased ~~$308.7~~$174.5 million for the three months ended ~~June 30, 2020,~~March 31, 2021, as compared to the three months ended ~~June 30, 2019.~~March 31, 2020. These decreases were primarily attributable to the significantly lower activity levels following the depressed oil prices and economic slowdown caused by the COVID-19 pandemic that negatively impacted E&P completions activity. As a percentage of pressure pumping segment revenues (including idle fees), pressure pumping cost of services was ~~63.6%~~75.7% for the three months ended ~~June 30, 2020,~~March 31, 2021, as compared to ~~72.6%~~76.0% for the three months ended ~~June 30, 2019. The decrease in our cost of services percentage was primarily attributable to the idle fees revenue.~~March 31, 2020. Excluding idle fees revenue of ~~$32.6~~$4.3 million and $1.5 million recorded during the three months ended March 31, 2021 and 2020, respectively, our pressure pumping cost of services as a percentage of pressure pumping revenues for the three months ended ~~June 30,~~March 31, 2021 and 2020, was approximately ~~92.7%. The increase in our~~77.8% and 76.3%, respectively. Furthermore, during the three months ended March 31, 2021 the company absorbed certain cost of services ~~as a percentage~~during the eight days of ~~revenue (excluding idle fees)~~severe weather conditions experienced in February 2021, which negatively impacted our ~~pressure pumping segment was attributable to the pricing pressure on our services resulting from significantly lower demand for our services and E&P completions activity.~~profitability.

General and Administrative Expenses. General and administrative expenses decreased ~~27.1%~~19.0%, or ~~$7.6~~$4.7 million, to ~~$20.3~~$20.2 million for the three months ended ~~June 30, 2020,~~March 31, 2021, as compared to ~~$27.9~~$24.9 million for the three months ended ~~June 30, 2019.~~March 31, 2020. The net decrease was primarily attributable to a decrease during 2021 in ~~(i) allowance for credit losses of $4.2 million, (ii) retention bonus of $1.7 million, (iii)~~ nonrecurring ~~advisory and~~ professional fees of ~~$1.4~~$6.1 million, which was primarily attributable to the Company's expanded audit committee internal review, pending SEC investigation and ~~(iv) payroll related expenses of $1.0 million, partially~~shareholder litigation, which was offset by a net increase of ~~$0.7~~approximately $1.4 million in our other remaining general and administrative expenses.

Impairment Expense. There was no impairment expense recorded during the three months ended March 31, 2021, as compared to $16.7 million of goodwill and equipment impairment expense recorded during the three months ended March 31, 2020 in connection with the then depressed market conditions and utilization of our equipment.

Depreciation and Amortization. Depreciation and amortization ~~increased 13.2%~~decreased of 16.7%, or ~~$4.7~~$6.7 million, to $33.5 million for the three months ended March 31, 2021, as compared to $40.2 million for the three months ended ~~June 30, 2020, as compared to $35.5 million for the three months ended June 30, 2019.~~March 31, 2020. The ~~increase~~decrease was primarily attributable to the ~~increase~~decrease in our fixed asset base, aspart of ~~June 30, 2020, resulting primarily from an increase~~which was attributable to the impairment of certain fixed assets in ~~our pressure pumping fleet capacity by 3.8% to 1,469,000 HHP as of June 30,~~ 2020.

Loss on Disposal of Assets. Loss on the disposal of assets decreased ~~72.0%~~34.3%, or ~~$22.5~~$6.8 million, to ~~$8.7~~$13.1 million for the three months ended ~~June 30, 2020,~~March 31, 2021, as compared to ~~$31.2~~$19.9 million for the three months ended ~~June 30, 2019.~~March 31, 2020. The decrease was primarily attributable to the decrease in ~~utilization of our equipment.~~equipment utilization. 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 ~~61.0%~~86.3%, or ~~$1.2~~$1.1 million, to ~~$0.8~~$0.2 million for the three months ended ~~June 30, 2020,~~March 31, 2021, as compared to ~~$2.0~~$1.3 million for the three months ended ~~June 30, 2019.~~March 31, 2020. The decrease in interest expense was primarily attributable to the decrease in our average debt balance during the three months ended ~~June 30, 2020~~March 31, 2021 compared to the three months ended ~~June 30, 2019.~~March 31, 2020. The Company repaid all of its borrowings under the ABL Credit Facility in 2020, and

had no outstanding borrowings during the three months ended March 31, 2021. The interest expense in the three months ended March 31, 2021 relates to the amortization of our capitalized loan origination cost.

Other (Income)/Expense. Other income increased to $1.8 million for the three months ended March 31, 2021. 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 the three months ended March 31, 2021.

Income ~~Tax Expense.~~Taxes. Total income tax benefit was ~~$6.5~~$6.7 million resulting in an effective tax rate of ~~20.0%~~24.6% for the three months ended ~~June 30, 2020,~~March 31, 2021, as compared to income tax ~~expense~~benefit of ~~$10.3~~$0.9 million or an effective tax rate of ~~22.1%~~10.4% for the three months ended ~~June 30, 2019.~~March 31, 2020. The income tax benefit recorded in the three months ended ~~June 30, 2020~~March 31, 2021 is primarily attributable to the ~~Company projecting a~~higher pre-tax loss in ~~2020~~2021 as compared to ~~a pre-tax income in 2019.~~2020. Furthermore, the change in the effective tax rate from ~~22.1%~~10.4% to ~~20.0%~~24.6% in the three months ended ~~June 30, 2020~~March 31, 2021 was primarily attributable to nondeductible expenses and discrete items such as stock compensation, ~~expense~~ reducing the benefit recorded for the pre-tax ~~loss.~~loss during the three months ended March 31, 2020.

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

(in thousands, except for percentages)
Six Months Ended June 30, Change

2020 2019 Variance %
Revenue $ 501,178
$ 1,075,673
$ (574,495 ) (53.4 )%
Cost of services ⁽¹⁾
369,041
767,741
(398,700 ) (51.9 )%
General and administrative expense ⁽²⁾
45,269
46,414
(1,145 ) (2.5 )%
Depreciation and amortization 80,377
68,599
11,778
17.2 %
Impairment expense 16,654
—
16,654
100.0 %
Loss on disposal of assets 28,588
50,425
(21,837 ) (43.3 )%
Interest expense 2,072
3,928
(1,856 ) (47.3 )%
Other expense 271
464
(193 ) (41.6 )%
Income tax expense (benefit) (7,370 ) 32,164
(39,534 ) (122.9 )%
Net income (loss) $ (33,724 ) $ 105,938
$ (139,662 ) (131.8 )%

Adjusted EBITDA ⁽³⁾
$ 100,334
$ 276,837
$ (176,503 ) (63.8 )%
Adjusted EBITDA Margin ⁽³⁾
20.0 % 25.7 % (5.7 )% (22.2 )%

Pressure pumping segment results of operations:
Revenue $ 490,735
$ 1,047,931
$ (557,196 ) (53.2 )%
Cost of services $ 360,215
$ 745,757
$ (385,543 ) (51.7 )%
Adjusted EBITDA ⁽³⁾
$ 112,696
$ 282,228
$ (169,532 ) (60.1 )%
Adjusted EBITDA Margin ⁽⁴⁾
23.0 % 26.9 % (3.9 )% (14.5 )%

~~Six Months Ended June 30, 2020 Compared to the Six Months Ended June 30, 2019~~

Revenues from services other than pressure pumping decreased 62.4%, or $17.3 million, to $10.4 million for the six months ended June 30, 2020, as compared to $27.7 million for the six months ended June 30, 2019. The decrease in revenue from services other than pressure pumping was primarily attributable to the significant reduction in utilization experienced by our coiled tubing operations, which was driven by lower E&P completions activity following the depressed oil prices and impact of the COVID-19 pandemic.-23-

~~Cost of Services.~~ Cost of services decreased 51.9%, or $398.7 million, to $369.0 million for the six months ended June 30, 2020, as compared to $767.7 million during the six months ended June 30, 2019. Cost of services in our pressure pumping segment decreased $385.5 million for the six months ended June 30, 2020, as compared to the six months ended June 30, 2019. These decreases were primarily attributable to the significantly lower activity levels resulting from the depressed oil prices and

economic slowdown caused by the COVID-19 pandemic that negatively impacted E&P completions activity. As a percentage of pressure pumping segment revenues (including idle fees), pressure pumping cost of services increased to 73.4% for the six months ended June 30, 2020, as compared to 71.2% for the six months ended June 30, 2019. Excluding idle fees revenue of $34.1 million recorded during the six months ended June 30, 2020, our pressure pumping cost of services as a percentage of pressure pumping revenues for six months ended June 30, 2020, was approximately 78.9%. The increase in our cost of services as a percentage of revenue in our pressure pumping segment is attributable to the pricing pressure on our services resulting from significantly lower demand for our services and E&P completions activity.

~~General and Administrative Expenses.~~ General and administrative expenses decreased 2.5%, or $1.1 million, to $45.3 million for the six months ended June 30, 2020, as compared to $46.4 million for the six months ended June 30, 2019. The net decrease was primarily attributable to a decrease in (i) retention bonus of $3.5 million associated with personnel who joined us in 2019 as part of the Pioneer Pressure Pumping Acquisition, (ii) payroll and stock-based compensation expense of $3.1 million and (iii) property taxes and other general and administrative expense of $2.2 million, partially offset by a net increase of approximately $7.7 million paid in professional fees to legal and accounting consultants, which was primarily attributable to the Company's audit committee internal review, SEC investigation and shareholders' litigation.

~~Depreciation and Amortization.~~ Depreciation and amortization increased 17.2%, or $11.8 million, to $80.4 million for the six months ended June 30, 2020, as compared to $68.6 million for the six months ended June 30, 2019. The increase was primarily attributable to the increase in our fixed asset base as of June 30, 2020, resulting primarily from an increase in our pressure pumping fleet capacity by 3.8% to 1,469,000 HHP as of June 30, 2020.

~~Impairment Expense.~~ During the six months ended June 30, 2020, the depressed market conditions, crude oil prices and negative near-term outlook for the utilization of our assets, 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. There was no impairment expense during the six months ended June 30, 2019.

~~Loss on Disposal of Assets.~~ Loss on the disposal of assets decreased 43.3%, or $21.8 million, to $28.6 million for the six months ended June 30, 2020, as compared to $50.4 million for six months ended June 30, 2019. The decrease is primarily attributable to the decrease in utilization of 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 47.3%, or $1.9 million, to $2.1 million for the six months ended June 30, 2020, as compared to $3.9 million for the six months ended June 30, 2019. The decrease in interest expense was primarily attributable to the decrease in our average debt balance during the six months ended June 30, 2020 compared to the six months ended June 30, 2019.

~~Income Tax Expense.~~ Total income tax benefit was $7.4 million resulting in an effective tax rate of 17.9% for the six months ended June 30, 2020, as compared to income tax expense of $32.2 million or an effective tax rate of 23.3% for the six months ended June 30, 2019. The income tax benefit recorded in the six months ended June 30, 2020 is primarily attributable to the Company projecting a pre-tax loss in 2020 as compared to a pre-tax income in 2019. Furthermore, the change in the effective tax rate from 23.3% to 17.9% in the six months ended June 30, 2020 was primarily attributable to nondeductible expenses and discrete items such as stock compensation expense reducing the benefit recorded for the pre-tax loss.

Liquidity and Capital Resources

Our liquidity is currently provided by (i) existing cash balances, (ii) operating cash flows and (iii) borrowings under our ~~revolving credit facility (“~~ABL Credit ~~Facility”).~~Facility, if any. Our primary uses of cash will be to continue to fund our operations, support growth opportunities and satisfy ~~any~~ future debt ~~payments.~~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. ~~With the current depressed oil and gas market conditions, we~~We believe our remaining monthly availability under our ABL Credit ~~facility~~Facility will ~~continue to~~ be adversely impacted byif the ~~expected decline in our customers’ activity.~~current depressed oil and gas market conditions continue or worsen.

As of ~~June 30, 2020,~~March 31, 2021, we had no borrowings under our ABL Credit Facility, and our total liquidity was approximately ~~$50.4~~$113.7 million, consisting of cash and cash equivalents of $55.9 million and $57.8 million of availability under our ABL Credit Facility.

As of May 3, 2021, our total liquidity was approximately $110.9 million, consisting of cash and cash equivalents of ~~$37.3~~$51.1 million ~~and $13.1~~and $59.8 million of availability under our ABL Credit Facility.

AsIn 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 and a reduction in the COVID-19 infection rate and the administration of ~~July 31, 2020,~~COVID-19 vaccines, which we believe will improve the demand for crude oil and consequently the demand for our ~~total liquidity was approximately $43.1 million, consisting~~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 ~~cash~~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 ~~equivalents of $22.6 million and $20.5 million of availability under our ABL Credit Facility.~~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~~on 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.

The global public health crisis associated with the COVID-19 pandemic has and is anticipated to continue to have an adverse effect on global economic activity for the immediate future and has resulted in travel restrictions, business closures and the institution of quarantining and other restrictions on movement in many communities. The slowdown in global economic activity attributable to COVID-19 has resulted in a dramatic decline in the demand for energy which directly impacts our industry and the Company. In addition, global crude oil prices experienced a collapse starting in early March 2020. As a result of these developments, the Company expects a material adverse impact on the oil field services we provide and our revenue, results of operations and cash flows. These situations are rapidly changing and additional impacts to the business may arise that we are not aware of currently and the depressed oil and gas industry may take a longer time to recover thereby significantly impacting on our revenue, results of operations and cash flows for a longer period of time.

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, 2020~~March 31, 2021 was ~~approximately $16.8~~approximately $61.5 million and was approximately ~~$24.2~~$63.5 million as of ~~July 31, 2020.~~May 3, 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.

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 weighted average interest rate for our~~There were no borrowings under the ABL Credit Facility for the ~~six~~three months ended ~~June 30,~~March 31, 2021. As ofMarch 31, 2020, our outstanding borrowings under the ABL Credit Facility were $110 million, which was ~~3.2%.~~subsequently fully repaid before the end of 2020.

In July 2017, the United Kingdom's Financial Conduct Authority, which regulates LIBOR, announced that it ~~intend~~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.

-24-

Future Sources and Use of Cash and Contractual Obligations

~~Future~~ 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 ~~active~~existing assets, ~~depending on fleet utilization, customer demand and market conditions.~~including costs to convert our existing conventional Tier II equipment to lower emissions equipment—Tier IV DGB equipment.

We ~~anticipate~~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. ~~Our cash flows from operations~~However, as noted elsewhere in this quarterly report, we will ~~be generated from services~~continually evaluate opportunities to improve our service offerings and other investment and acquisition opportunities that we ~~provide to our customers and idle fees if a customer (Pioneer) decides to idle committed fleets and we are not able to deploy~~believe would enhance the ~~idled fleets to another customer. During times when there is a significant reduction in overall demand for our services, the idle fees could represent a material portion~~competitiveness of our ~~revenues~~business. Depending upon market conditions and cash flows from operations. The total amounts of idle fees earned and billed to our customer that was included in accounts receivable as of June 30, 2020, which we expect to collect in the near-term, is approximately $32.6 million. Our maintenance capital expenditures are dependent on our operational activity and the intensity on the equipment, among other factors, ~~which could vary throughout the year.~~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 April 30, 2021.~~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. In the current economic environment, it is not probable that we ~~would~~will exercise these options before they expire.

During the six months ended June 30, 2020, we repaid all our borrowings under our ABL Credit Facility of approximately $130.0 million with cash flows from operations and our available cash. Our objective is to maintain a conservative leverage ratio.

In the normal course of business, we enter into various contractual obligations and routine growth and maintenance capital expenditures that impact on our future liquidity. There were no other known future material contractual obligations as of ~~June 30, 2020.~~March 31, 2021.

Cash and Cash Flows

The following table sets forth the historical cash flows for the ~~six~~three months ended ~~June 30, 2020~~March 31, 2021 and ~~2019:~~2020:

Six Months Ended June 30,
($ in thousands) 2020 2019
Net cash provided by (used in):
Operating activities $ 96,910
$ 150,851
Investing activities $ (78,025 ) $ (324,334 )
Financing activities $ (130,615 ) $ 77,062


	Three Months Ended March 31,
($ in thousands)	2021		2020

Net cash provided by operating activities	$	17,008	$	61,724
Net cash used in investing activities	$	(22,270)	$	(46,557)
Net cash used in financing activities	$	(7,651)	$	(20,486)

Cash Flows From Operating Activities

Net cash provided by operating activities was ~~$96.9~~$17.0 million for the ~~six~~three months ended ~~June 30, 2020,~~March 31, 2021, compared to ~~net cash provided by operating activities of $150.9~~$61.7 million for the ~~six~~three months ended ~~June 30, 2019.~~March 31, 2020. The net decrease of ~~$53.9~~$44.7 million was primarily due to the decrease in our activity levels resulting from the decrease in the demand for our services, driven by the depressed crude oil prices and economic impact of the COVID-19 pandemic on our ~~industry.~~industry, and partially offset with the timing of collections of our receivables from customers and payments to vendors. Our effectively utilized fleet count decreased to approximately 10.3 active fleets during the three months ended March 31, 2021 from approximately 18.6 active fleets for the three months ended March 31, 2020.

Cash Flows From Investing Activities

Net cash used in investing activities decreased to ~~$78.0~~$22.3 million for the ~~six~~three months ended ~~June 30, 2020,~~March 31, 2021, from ~~$324.3~~$46.6 million for the ~~six~~three months ended ~~June 30, 2019.~~March 31, 2020. The decrease was primarily attributable to the ~~Company’s initiatives~~lower maintenance capital expenditures associated with lower activity levels during the three months ended March 31, 2021, compared to ~~significantly reduce growth~~higher activity levels and associated higher maintenance capital expenditures during the ~~six~~three months ended June 30, 2020 following the depressed oil and gas market and decreased demand for our services. During the six months ended June 30, 2019, the Company acquired and paid approximately $110.0 million for the purchase of 510,000 HHP, 4 coiled tubing units and maintenance yard (associated with the Pioneer Pressure Pumping Acquisition), and also made cash deposits of approximately $102.9 million to its equipment manufacturers for ~~DuraStim®~~ ~~hydraulic fracturing equipment including option fees deposit.~~

March 31, 2020.

Cash Flows From Financing Activities

Net cash used in financing activities ~~was $130.6~~decreased to $7.7 million for the ~~six~~three months ended ~~June 30, 2020, and net cash provided by financing activities was $77.1~~March 31, 2021, from $20.5 million for the ~~six~~three months ended ~~June 30, 2019.~~March 31, 2020. The ~~net~~ decrease in cash from financing activities during the ~~six~~three months ended ~~June 30, 2020~~March 31, 2021 was primarily driven by the repayment of $20.0 million of our ~~outstanding~~ borrowings under our ABL Credit Facility ~~of $130.0 million,~~during the three months ended March 31, 2020, compared to ~~net~~no repayments of borrowings ~~under our ABL Credit Facility of $80.0 million~~ during the ~~six~~three months ended ~~June 30, 2019.~~March 31, 2021.

-25-

Off-Balance Sheet Arrangements

We had no off-balance sheet arrangements as of ~~June 30, 2020.~~March 31, 2021.

Critical Accounting Policies and Estimates

There have been no material changes during the ~~six~~three months ended ~~June 30, 2020~~March 31, 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~~"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, 2020,~~March 31, 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.

-26-

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.~~Form 10-Q. Based upon that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were ~~not~~ effective at the reasonable assurance level as of June 30, 2020, and notwithstanding the material weaknesses in our internal control over financial reporting described below, our management has concluded that our financial statements in this Quarterly Report present fairly, in all material respects, our financial position, results of operations and cash flows for the periods presented in accordance with accounting principles generally accepted in the United States of America (“GAAP”).

~~Management’s Report on Internal Control over Financial Reporting~~

The management of ProPetro Holding Corp. is responsible for establishing and maintaining adequate internal control over financial reporting for the Company, as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act. ProPetro Holding Corp. maintains a system of internal accounting controls designed to provide reasonable assurance, at a reasonable cost, that assets are safeguarded against loss or unauthorized use and that the financial records are adequate and can be relied upon to produce financial statements in accordance with GAAP. The internal control system is augmented by written policies and procedures, an internal audit program and the selection and training of qualified personnel. This system includes policies that require adherence to ethical business standards and compliance with all applicable laws and regulations.

There are inherent limitations to the effectiveness of any control system. A control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Also, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within the Company will be detected. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. The Company intends to continually improve and refine its internal controls.

Our management, with the participation of our Principal Executive Officer and Principal Financial Officer, conducted an evaluation of the effectiveness of the design and operation of our internal control over financial reporting as of DecemberMarch 31, 2019 based on criteria established in the 2013 Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”). Based on the evaluation under these criteria, management determined, based upon the existence of the material weaknesses identified and previously reported in our Form 10-K and described below, that we did not maintain effective internal control over financial reporting as of December 31, 2019. Due to the existence of the material weaknesses described below, our internal control over financial reporting remained ineffective as of June 30, 2020.

A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that a reasonable possibility exists that a material misstatement of our annual or interim financial statements would not be prevented or detected on a timely basis.

~~Control Environment~~

We have identified deficiencies in the principles associated with the control environment component of the COSO framework. Specifically, these control deficiencies constitute material weaknesses, either individually or in the aggregate, relating to the following COSO principles: (i) the organization demonstrates a commitment to integrity and ethical values, (ii) the board of directors demonstrates independence from management and exercises oversight of the development and performance of internal control, (iii) management establishes, with board oversight, structures, reporting lines, and appropriate authorities and responsibilities in pursuit of objectives, (iv) the organization demonstrates a commitment to attract, develop, and retain competent individuals in alignment with objectives, and (v) the organization holds individuals accountable for their internal control related responsibilities in the pursuit of objectives.

Our senior management did not establish and promote a control environment with an appropriate tone of compliance and control consciousness throughout the entire Company. The Company did not sufficiently promote, monitor or enforce adherence to its Code of Conduct and Ethics. Additionally, the recently concluded expanded audit committee review found that there was a general lack of focus on promoting a culture of compliance within the Company. Results of poor tone at the top included: (i) certain whistleblower allegations were not properly investigated and elevated to the Committee, (ii) the lack of an employee expense review and approval policy, (iii) two instances of non-compliance with the Company’s Insider Trading Policy, and (iv) instances of non-compliance with the Code of Conduct and Ethics policies.

~~This material weakness in the control environment contributed to material weaknesses in the following components of the COSO framework.~~

~~Information and Communication~~

We have identified deficiencies in the principles associated with the information and communication component of the COSO framework. Specifically, these control deficiencies constitute material weaknesses, either individually or in the aggregate, relating to the following COSO principles: (i) the organization internally communicates information, including objectives and responsibilities for internal control, necessary to support the functioning of internal control, and (ii) the organization communicates with external parties regarding matters affecting the functioning of internal control.

Factors contributing to the material weakness included miscommunication between management and the Board regarding the conditionality of certain contracts that resulted in the non-disclosure of such contract commitments and the impact of such commitments on the Company’s future liquidity.

~~Control Activities~~

We have identified deficiencies in the principles associated with the control activities component of the COSO framework. Specifically, these control deficiencies constitute material weaknesses, either individually or in the aggregate, relating to the following COSO principles: (i) the organization selects and develops control activities that contribute to the mitigation of risks to the achievement of objectives to acceptable levels and (ii) the organization deploys control activities through policies that establish what is expected and procedures that put policies into action.

The Company’s failure to maintain appropriate tone at the top had a pervasive impact, and as such, resulted in a risk that could have impacted virtually all financial statement account balances and disclosures.

~~The COSO component material weaknesses described above contributed to the following material weakness within our system of internal control over financial reporting at the control activity level.~~

~~Related Parties~~

We did not maintain controls designed to sufficiently identify, evaluate, and disclose related party transactions. As a result, two related party transactions were entered into that were not identified by the Company’s controls and given consideration of appropriate disclosure.

~~Remediation Plan and Status~~

Our remediation efforts to the identified material weaknesses are ongoing, and we will continue our initiatives to implement and document policies, procedures, and internal controls. The Board and management have implemented, among other items, the following measures to address the material weaknesses identified:

~~Appointed new executive officers with extensive public company experience to improve the tone at the top, communication with the Board and compliance with policies within the Company.~~

Enhanced certain of the Company’s policies, including the Code of Ethics and Conduct, Expense Reimbursement, Travel and Entertainment, and Delegation of Responsibilities and Authority. Additionally, the Company enhanced or implemented control activities to monitor compliance with such policies.

~~Designed and implemented control activities related to the identification of, approval of, and disclosure of related party transactions.~~

~~Designed and implemented control activities related to the identification and approval of potential conflicts of interest.~~

~~Designed and implemented control activities related to the evaluation of whistleblower allegations.~~

~~Formed a disclosure committee and appointed a Chief Disclosure Officer to provide improved corporate governance related to disclosures the Company provides to the public and other external parties.~~

Our remediation of the identified material weaknesses and strengthening our internal control environment is ongoing and will require a substantial effort. We will continue to evaluate the design and implementation and operating effectiveness of the new and existing controls that address all the material weaknesses we identified as of December 31, 2019. The material weaknesses cannot be considered remediated until the applicable controls have operated for a sufficient period of time and management has concluded, through testing for a period of time, that these controls are designed and operating effectively. Accordingly, we will continue to monitor and evaluate the effectiveness of our internal control over financial reporting in the areas affected by the material weaknesses described above.2021.

Changes in Internal Control over Financial Reporting

~~Except as described above, there were no~~No changes in our system of internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) ~~that~~ occurred during the quarter ended ~~June 30, 2020~~March 31, 2021 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

-27-

PART II – OTHER INFORMATION

ITEM 1. Legal Proceedings

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 March 31, 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.

ITEM 1A. Risk Factors

There have been no material changes to the risk factors disclosed in Part I, Item ~~1A.~~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.

-28-

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 ~~herein~~ to Exhibit 3.1 to ~~ProPetro Holding Corp.’s~~the Company's Current Report on Form 8-K, dated April 14, 2020).
~~4.1~~10.1+*		~~Rights Agreement, dated as~~2021 Form of ~~April 14, 2020, by and between~~ ProPetro Holding Corp. 2020 Long Term Incentive Plan Restricted Stock Unit Grant Notice and ~~American~~Restricted Stock ~~Transfer & Trust Company, LLC (incorporated by reference herein to Exhibit 4.1 to~~Unit Agreement (Employees).
10.2+*		2021 Form of ProPetro Holding Corp.~~’s Current Report on Form 8-K, dated April 14, 2020).~~ 2020 Long Term Incentive Plan Performance Share Unit Grant Notice and Performance Share Unit Agreement.
~~10.1~~31.1*		Waiver to Credit Agreement, dated as of June 22, 2020 by and among ProPetro Holding Corp., ProPetro Services, Inc., Barclays Bank PLC, as the Agent, the Collateral Agent, a Letter of Credit Issuer and Swingline Lender, and each of the Lenders from time to time party thereto (incorporated by reference herein to Exhibit 10.1 to ProPetro Holding Corp.’s Current Report on Form 8-K, dated June 23, 2020).
~~10.2+~~	~~ProPetro Services, Inc. Amended and Restated Executive Severance Plan (incorporated by reference herein to Exhibit 10.1 to ProPetro Holding Corp.’s Current Report on Form 8-K, dated April 10, 2020).~~
~~10.3+~~	Letter Agreement dated April 9, 2020, by and between David Sledge and ProPetro Holding Corp. (incorporated by reference herein to Exhibit 10.3 to ProPetro Holding Corp.’s Current Report on Form 8-K, dated April 10, 2020).
~~10.4+~~	Participation Agreement pursuant to the ProPetro Services, Inc. Amended and Restated Executive Severance Plan, between Darin G. Holderness and ProPetro Services, Inc., dated April 10, 2020 (incorporated by reference herein to Exhibit 10.2 to ProPetro Holding Corp.’s Current Report on Form 8-K, dated April 10, 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



+			Indicates management contracts or compensatory plans or arrangements.
*			Filed herewith.
**			Furnished herewith.

-29-

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~~May 6, ~~2020~~2021

By:

/s/ Phillip A. Gobe

Phillip A. Gobe

Chief Executive Officer and Chairman of the Board

(Principal Executive Officer)

By:

/s/ ~~Darin G. Holderness~~David S. Schorlemer

~~Darin G. Holderness~~David S. Schorlemer

Chief Financial Officer

(Principal Financial Officer)

By:

/s/ Elo Omavuezi

Elo Omavuezi

Chief Accounting Officer

(Principal Accounting Officer)

~~-40-~~-30-



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


				Page
			Cautionary Note Regarding Forward-Looking Statements	ii

					~~Page~~
	~~Cautionary Note Regarding Forward-Looking Statements~~	ii

PART I – FINANCIAL INFORMATION
Item 1.			Financial Statements (Unaudited)
			Condensed Consolidated Balance Sheets as of ~~June 30, 2020~~ March 31, 202 1 and December 31, ~~2019~~20 2 0	1
			Condensed Consolidated Statements of Operations for the three ~~and six~~ months ended ~~June 30, 2020~~March 31 , 202 1 and ~~2019~~20 20	2
			Condensed Consolidated Statements of Shareholders' Equity for the three ~~and six~~ months ended ~~June, 2020~~March 31 , 202 1 and ~~2019~~20 20	3
			Condensed Consolidated Statements of Cash Flows for the ~~six~~t hree months ended ~~June 30, 2020~~ March 31 , 202 1 and ~~2019~~20 20	4
			Notes to Condensed Consolidated Financial Statements	5
Item 2.			Management’s Discussion and Analysis of Financial Condition and Results of Operations	2217
Item 3.			Quantitative and Qualitative Disclosures About Market Risk	3326
Item 4.			Controls and Procedures	3427

PART II – OTHER INFORMATION
Item 1.			Legal Proceedings	3728
Item 1A.			Risk Factors	3728
Item 2.			Unregistered Sales of Equity Securities and Use of Proceeds	3728
Item 3.			Defaults Upon Senior Securities	3728
Item 4.			Mine Safety Disclosures	3828
Item 5.			Other Information	3828
Item 6.			Exhibits	3929
			Signatures	4030



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



	June 30, 2020		December 31, 2019
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	37,306	$	149,036
Accounts receivable - net of allowance for credit losses of $1,497 and $1,049, respectively	65,554		212,183
Inventories	2,805		2,436
Prepaid expenses	5,061		10,815
Other current assets	1,103		1,121
Total current assets	111,829		375,591
PROPERTY AND EQUIPMENT - net of accumulated depreciation	978,749		1,047,535
OPERATING LEASE RIGHT-OF-USE ASSETS	851		989
OTHER NONCURRENT ASSETS:
Goodwill	—		9,425
Other noncurrent assets	2,173		2,571
Total other noncurrent assets	2,173		11,996
TOTAL ASSETS	$	1,093,602	$	1,436,111
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	31,233	$	193,096
Operating lease liabilities	317		302
Finance lease liabilities	—		2,831
Accrued and other current liabilities	27,719		36,343
Accrued interest payable	—		394
Total current liabilities	59,269		232,966
DEFERRED INCOME TAXES	95,268		103,041
LONG-TERM DEBT	—		130,000
NONCURRENT OPERATING LEASE LIABILITIES	636		799
Total liabilities	155,173		466,806
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,100,889,230 and 100,624,099 shares issued, respectively	101		101
Additional paid-in capital	829,477		826,629
Retained earnings	108,851		142,575
Total shareholders’ equity	938,429		969,305
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	1,093,602	$	1,436,111



	Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019
REVENUE - Service revenue	$	106,109		$	529,494		$	501,178		$	1,075,673
COSTS AND EXPENSES
Cost of services (exclusive of depreciation and amortization)	68,193			386,218			369,041			767,741
General and administrative (inclusive of stock-based compensation)	20,331			27,889			45,269			46,414
Depreciation and amortization	40,173			35,482			80,377			68,599
Impairment expense	—			—			16,654			—
Loss on disposal of assets	8,734			31,198			28,588			50,425
Total costs and expenses	137,431			480,787			539,929			933,179
OPERATING INCOME (LOSS)	(31,322		)	48,707			(38,751		)	142,494
OTHER EXPENSE:
Interest expense	(791		)	(2,026		)	(2,072		)	(3,928		)
Other expense	(267		)	(276		)	(271		)	(464		)
Total other expense	(1,058		)	(2,302		)	(2,343		)	(4,392		)
INCOME (LOSS) BEFORE INCOME TAXES	(32,380		)	46,405			(41,094		)	138,102
INCOME TAX (EXPENSE) BENEFIT	6,460			(10,272		)	7,370			(32,164		)
NET INCOME (LOSS)	$	(25,920	)	$	36,133		$	(33,724	)	$	105,938

NET INCOME (LOSS) PER COMMON SHARE:
Basic	$	(0.26	)	$	0.36		$	(0.33	)	$	1.06
Diluted	$	(0.26	)	$	0.35		$	(0.33	)	$	1.02

WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic	100,821			100,425			100,754			100,329
Diluted	100,821			104,379			100,754			104,181



	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



	Six Months Ended June 30, 2019
	Common Stock
	Shares	Amount		Additional Paid-In Capital		Retained Earnings (Accumulated Deficit)			Total
BALANCE - January 1, 2019	100,190	$	100	$	817,690	$	(20,435	)	797,355
Stock-based compensation cost	—	—		1,829		—			1,829
Issuance of equity awards, net	104	—		552		—			552
Net income	—	—		—		$	69,805		69,805
BALANCE - March 31, 2019	100,294	$	100	$	820,071	$	49,370		$	869,541
Stock-based compensation cost	—	—		2,840		—			2,840
Issuance of equity awards, net	257	1		522		—			523
Net income	—	—		—		36,133			36,133
BALANCE - June 30, 2019	100,551	101		823,433		85,503			909,037



($ in thousands)

Balance - January 1, 2020	$	1,049
Provision for credit losses during the period	4,291
Provision for credit losses no longer required	(3,843		)
Balance - June 30, 2020	$	1,497



($ in thousands)
			Estimated fair value measurements
	Balance		Quoted prices in active market (Level 1)		Significant other observable inputs (Level 2)		Significant other unobservable inputs (Level 3)		Total gains (losses)
June 30, 2020:
Property and equipment, net	$	—	$	—	$	—	$	—	$	—
Goodwill	$	—	$	—	$	—	$	—	$	—
December 31, 2019:
Property and equipment, net	$	2,000	$	—	$	2,000	$	—	$	(3,405	)
Goodwill	$	—	$	—	$	—	$	—	$	—




	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 June 30, 2020	$	1,052,915	$	40,687		$	1,093,602

	Three Months Ended June 30, 2019
	Pressure Pumping		All Other			Total
Service revenue	$	515,867	$	13,627		$	529,494
Adjusted EBITDA	$	131,187	$	(4,625	)	$	126,562
Depreciation and amortization	$	34,023	$	1,459		$	35,482
Goodwill at December 31, 2019	$	9,425	$	—		$	9,425
Capital expenditures	$	156,542	$	4,677		$	161,219
Total assets at December 31, 2019	$	1,381,811	$	54,300		$	1,436,111



	Number of Shares		Weighted Average Exercise Price
Outstanding at January 1, 2020	4,300,088		$	5.03
Granted	—		$	—
Exercised	—		$	—
Forfeited	(70,960	)	$	14.00
Expired	(5,619	)	$	14.00
Outstanding at June 30, 2020	4,223,509		$	4.87
Exercisable at June 30, 2020	4,086,657		$	4.57



	Number of Shares		Weighted Average Grant Date Fair Value
Outstanding at January 1, 2020	613,217		$	18.75
Granted	1,143,230		$	7.05
Vested	(202,493	)	$	18.22
Forfeited	(285,157	)	$	15.91
Canceled	—		$	—
Outstanding at June 30, 2020	1,268,797		$	8.93



Period Granted	Target Shares Outstanding at January 1, 2020	Target Shares Granted	Target Shares Vested		Target Shares Forfeited		Target Shares Outstanding at June 30, 2020	Weighted Average Grant Date Fair Value per Share
2017	151,492	—	(151,492	)	—		—	$	10.73
2018	156,576	—	—		(72,254	)	84,322	$	27.51
2019	214,553	—	—		(88,235	)	126,318	$	34.82
2020	—	966,242			(125,391	)	840,851	$	9.42
Total	522,621	966,242	(151,492	)	(285,880	)	1,051,491	$	13.92



(in thousands, except for percentages)	Three Months Ended June 30,						Change
	2020			2019			Variance			%
Revenue	$	106,109		$	529,494		$	(423,385	)	(80.0	)%
Cost of services ⁽¹⁾	68,193			386,218			(318,025		)	(82.3	)%
General and administrative expense ⁽²⁾	20,331			27,889			(7,558		)	(27.1	)%
Depreciation and amortization	40,173			35,482			4,691			13.2	%
Loss on disposal of assets	8,734			31,198			(22,464		)	(72.0	)%
Interest expense	791			2,026			(1,235		)	(61.0	)%
Other expense	267			276			(9		)	(3.3	)%
Income tax expense (benefit)	(6,460		)	10,272			(16,732		)	(162.9	)%
Net income (loss)	$	(25,920	)	$	36,133		$	(62,053	)	(171.7	)%

Adjusted EBITDA ⁽³⁾	$	25,410		$	126,562		$	(101,152	)	(79.9	)%
Adjusted EBITDA Margin ⁽³⁾	23.9		%	23.9		%	—		%	—	%

Pressure pumping segment results of operations:
Revenue	$	103,815		$	515,867		$	(412,052	)	(79.9	)%
Cost of services	$	65,991		$	374,653		$	(308,662	)	(82.4	)%
Adjusted EBITDA ⁽³⁾	$	34,030		$	131,187		$	(97,157	)	(74.1	)%
Adjusted EBITDA Margin ⁽⁴⁾	32.8		%	25.4		%	7.4		%	29.1	%


~~(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.