UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q


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

For the quarterly period ended ~~September~~June 30, ~~2022~~2023


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

For the transition period from to

Commission File Number: 001-38035

ProPetro Holding Corp.

(Exact name of registrant as specified in its charter)


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

1706 South Midkiff,

Midland, Texas 79701

(Address of principal executive offices)

(432) 688-0012

(Registrant’s telephone number, including area code)

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


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

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

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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 November 1, 2022,~~at July 31, 2023, was ~~114,554,085.~~112,772,097.

PROPETRO HOLDING CORP.

TABLE OF CONTENTS


		Page
	Cautionary Note Regarding Forward-Looking Statements	ii

PART I – FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
	Condensed Consolidated Balance Sheets as of ~~September~~Ju ne 30 ~~2022~~, 2023 and December 31, ~~2021~~2022	1
	Condensed Consolidated Statements of Operations for the three and ~~nine~~six months ended ~~September~~June ~~30,~~3 0 , 2023 and 2022 ~~and 2021~~	2
	Condensed Consolidated Statements of Shareholders' Equity for the three and ~~nine~~six months ended ~~September~~June ~~30,~~3 0 , 2023 and 2022 ~~and 2021~~	3
	Condensed Consolidated Statements of Cash Flows for the ni nesix months ended ~~September~~June ~~30,~~3 0 , 2023 and 2022 ~~and 2021~~	4
	Notes to Condensed Consolidated Financial Statements	56
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	2025
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3237
Item 4.	Controls and Procedures	3338

PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	3439
Item 1A.	Risk Factors	3439
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3440
Item 3.	Defaults Upon Senior Securities	3440
Item 4.	Mine Safety Disclosures	3440
Item 5.	Other Information	3440
Item 6.	Exhibits	3541
	Signatures	3642

-i-

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q (this "Form 10-Q") contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities and Exchange Act of 1934, as amended (the "Exchange Act"). All statements other than statements of historical facts contained in this Form 10-Q are forward-looking statements. Forward-looking statements are all statements other than statements of historical facts, and give our expectations or forecasts of future events as of the effective date of this Form 10-Q. Words such as "may," "could," "plan," "project," "budget," "predict," "pursue," "target," "seek," "objective," "believe," "expect," "anticipate," "intend," "estimate," "will," "should" and similar expressions are generally used 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.~~expenditures, our fleet conversion strategy and our share repurchase program. 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:

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

•central bank policy actions, bank failures and associated liquidity risks and other factors;

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

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

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

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

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

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

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

•competitive conditions in our industry;

•our ability to attract and retain employees;

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

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

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

•changes in the availability and cost of capital;

•our ability to successfully implement our business plan, including execution of potential mergers and acquisitions;

•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 increasing interest rates) for the Company and our customers;

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

•~~operational challenges from the COVID-19 pandemic~~increases in tax rates or types of taxes enacted that specifically impact E&P 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;

•related operations resulting in changes in ~~our tax status;~~the amount of taxes owed by us;

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

-ii-

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

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

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

•the projected timing, purchase price and number of shares purchased under our share repurchase program, the sources of funds under the repurchase program and the impacts of the repurchase program;

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

•exposure to cyber-security events which could cause operational disruptions or reputational harm;

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

•the effects of current and future litigation.

Whether actual results and developments will conform with our expectations and predictions contained in forward-looking statements is subject to a number of risks and uncertainties which could cause actual results to differ materially from such expectations and predictions, including, without limitation, in addition to those specified in the text surrounding such statements, the risks described under Part II, Item 1A, "Risk Factors" in this Form 10-Q and elsewhere throughout this report, the risks described under Part I, Item 1A, "Risk Factors" in our Form 10-K for the year ended December 31, ~~2021,~~2022, filed with the SEC (the "Form 10-K") and elsewhere throughout that report, and other risks, many of which are beyond our control.

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

-iii-

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)

(Unaudited)


		September 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
ASSETS	ASSETS					ASSETS
CURRENT ASSETS:	CURRENT ASSETS:					CURRENT ASSETS:
Cash and cash equivalents		$	43,208	$	111,918
Accounts receivable - net of allowance for credit losses of $217 and $217, respectively		210,522		128,148
Cash, cash equivalents and restricted cash						Cash, cash equivalents and restricted cash	$	62,113	$	88,862
Accounts receivable - net of allowance for credit losses of $202 and $419, respectively						Accounts receivable - net of allowance for credit losses of $202 and $419, respectively	251,104		215,925
Inventories	Inventories	3,944		3,949		Inventories	18,159		5,034
Prepaid expenses	Prepaid expenses	4,026		6,752		Prepaid expenses	8,607		8,643
Short-term investment, net	Short-term investment, net	8,503		—		Short-term investment, net	6,437		10,283
Other current assets	Other current assets	30,038		297		Other current assets	704		38
Total current assets	Total current assets	300,241		251,064		Total current assets	347,124		328,785
PROPERTY AND EQUIPMENT - net of accumulated depreciation	PROPERTY AND EQUIPMENT - net of accumulated depreciation	841,513		808,494		PROPERTY AND EQUIPMENT - net of accumulated depreciation	1,001,109		922,735
OPERATING LEASE RIGHT-OF-USE ASSETS	OPERATING LEASE RIGHT-OF-USE ASSETS	600		409		OPERATING LEASE RIGHT-OF-USE ASSETS	5,672		3,147
OTHER NONCURRENT ASSETS:	OTHER NONCURRENT ASSETS:					OTHER NONCURRENT ASSETS:
Goodwill						Goodwill	23,624		23,624
Intangible assets - net of amortization						Intangible assets - net of amortization	53,480		56,345
Other noncurrent assets	Other noncurrent assets	1,252		1,269		Other noncurrent assets	2,370		1,150
Total other noncurrent assets	Total other noncurrent assets	1,252		1,269		Total other noncurrent assets	79,474		81,119
TOTAL ASSETS	TOTAL ASSETS	$	1,143,606	$	1,061,236	TOTAL ASSETS	$	1,433,379	$	1,335,786

LIABILITIES AND SHAREHOLDERS’ EQUITY	LIABILITIES AND SHAREHOLDERS’ EQUITY					LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:	CURRENT LIABILITIES:					CURRENT LIABILITIES:
Accounts payable	Accounts payable	$	187,381	$	152,649	Accounts payable	$	218,147	$	234,299
Accrued and other current liabilities						Accrued and other current liabilities	57,022		49,027
Operating lease liabilities	Operating lease liabilities	490		369		Operating lease liabilities	1,125		854
Accrued and other current liabilities		65,946		20,767
Total current liabilities	Total current liabilities	253,817		173,785		Total current liabilities	276,294		284,180
DEFERRED INCOME TAXES	DEFERRED INCOME TAXES	59,127		61,052		DEFERRED INCOME TAXES	84,162		65,265
LONG-TERM DEBT						LONG-TERM DEBT	60,000		30,000
NONCURRENT OPERATING LEASE LIABILITIES	NONCURRENT OPERATING LEASE LIABILITIES	124		97		NONCURRENT OPERATING LEASE LIABILITIES	4,564		2,308
Total liabilities	Total liabilities	313,068		234,934		Total liabilities	425,020		381,753
COMMITMENTS AND CONTINGENCIES (Note 10)
COMMITMENTS AND CONTINGENCIES (Note 13)						COMMITMENTS AND CONTINGENCIES (Note 13)
SHAREHOLDERS’ EQUITY:	SHAREHOLDERS’ EQUITY:					SHAREHOLDERS’ EQUITY:
Preferred stock, $0.001 par value, 30,000,000 shares authorized, none issued, respectively	Preferred stock, $0.001 par value, 30,000,000 shares authorized, none issued, respectively	—		—		Preferred stock, $0.001 par value, 30,000,000 shares authorized, none issued, respectively	—		—
Common stock, $0.001 par value, 200,000,000 shares authorized, 104,426,520 and 103,437,177 shares issued, respectively		104		103
Common stock, $0.001 par value, 200,000,000 shares authorized, 112,957,976 and 114,515,008 shares issued, respectively						Common stock, $0.001 par value, 200,000,000 shares authorized, 112,957,976 and 114,515,008 shares issued, respectively	113		114
Additional paid-in capital	Additional paid-in capital	860,075		844,829		Additional paid-in capital	956,856		970,519
Accumulated deficit		(29,641)		(18,630)
Retained earnings (accumulated deficit)						Retained earnings (accumulated deficit)	51,390		(16,600)
Total shareholders’ equity	Total shareholders’ equity	830,538		826,302		Total shareholders’ equity	1,008,359		954,033
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	1,143,606	$	1,061,236	TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	1,433,379	$	1,335,786

See notes to condensed consolidated financial statements.

-1-

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)

(Unaudited)


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
REVENUE - Service revenue	REVENUE - Service revenue	$	333,014	$	250,099	$	930,776	$	628,444	REVENUE - Service revenue	$	435,249	$	315,083	$	858,819	$	597,763
COSTS AND EXPENSES	COSTS AND EXPENSES									COSTS AND EXPENSES
Cost of services (exclusive of depreciation and amortization)	Cost of services (exclusive of depreciation and amortization)	224,118		188,690		640,202		474,905		Cost of services (exclusive of depreciation and amortization)	297,791		218,813		578,277		416,083
General and administrative (inclusive of stock-based compensation)		28,190		21,348		85,031		59,079
General and administrative expenses (inclusive of stock-based compensation)										General and administrative expenses (inclusive of stock-based compensation)	29,021		25,135		57,767		56,842
Depreciation and amortization	Depreciation and amortization	30,417		33,531		93,734		100,253		Depreciation and amortization	52,889		40,969		103,687		78,973
Impairment expense	Impairment expense	—		—		57,454		—		Impairment expense	—		57,454		—		57,454
Loss on disposal of assets	Loss on disposal of assets	36,636		12,424		75,240		40,500		Loss on disposal of assets	3,065		12,978		25,145		22,947
Total costs and expenses	Total costs and expenses	319,361		255,993		951,661		674,737		Total costs and expenses	382,766		355,349		764,876		632,299
OPERATING INCOME (LOSS)	OPERATING INCOME (LOSS)	13,653		(5,894)		(20,885)		(46,293)		OPERATING INCOME (LOSS)	52,483		(40,266)		93,943		(34,536)
OTHER INCOME (EXPENSE):
OTHER (EXPENSE) INCOME:										OTHER (EXPENSE) INCOME:
Interest expense	Interest expense	(237)		(143)		(1,040)		(477)		Interest expense	(1,180)		(669)		(1,847)		(803)
Other income (expense)	Other income (expense)	(616)		(309)		9,749		1,178		Other income (expense)	72		6		(3,632)		10,364
Total other income (expense)		(853)		(452)		8,709		701
Total other (expense) income										Total other (expense) income	(1,108)		(663)		(5,479)		9,561
INCOME (LOSS) BEFORE INCOME TAXES	INCOME (LOSS) BEFORE INCOME TAXES	12,800		(6,346)		(12,176)		(45,592)		INCOME (LOSS) BEFORE INCOME TAXES	51,375		(40,929)		88,464		(24,975)
INCOME TAX (EXPENSE) BENEFIT	INCOME TAX (EXPENSE) BENEFIT	(2,768)		1,279		1,164		11,639		INCOME TAX (EXPENSE) BENEFIT	(12,118)		8,069		(20,474)		3,932
NET INCOME (LOSS)	NET INCOME (LOSS)	$	10,032	$	(5,067)	$	(11,012)	$	(33,953)	NET INCOME (LOSS)	$	39,257	$	(32,860)	$	67,990	$	(21,043)

NET INCOME (LOSS) PER COMMON SHARE:	NET INCOME (LOSS) PER COMMON SHARE:									NET INCOME (LOSS) PER COMMON SHARE:
Basic	Basic	$	0.10	$	(0.05)	$	(0.11)	$	(0.33)	Basic	$	0.34	$	(0.32)	$	0.59	$	(0.20)
Diluted	Diluted	$	0.10	$	(0.05)	$	(0.11)	$	(0.33)	Diluted	$	0.34	$	(0.32)	$	0.59	$	(0.20)

WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:	WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:									WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic	Basic	104,372		103,257		104,100		102,408		Basic	114,737		104,236		114,809		103,961
Diluted	Diluted	105,070		103,257		104,100		102,408		Diluted	114,796		104,236		115,102		103,961

See notes to condensed consolidated financial statements.

-2-

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY

(In thousands)

(Unaudited)


	Six Months Ended June 30, 2023
	Common Stock
	Shares	Amount		Additional Paid-In Capital		Retained Earnings (Accumulated Deficit)		Total
BALANCE - January 1, 2023	114,515	$	114	$	970,519	$	(16,600)	$	954,033
Stock-based compensation cost	—	—		3,536		—		3,536
Issuance of equity awards, net	656	1		(1)		—		—
Tax withholdings paid for net settlement of equity awards	—	—		(3,379)		—		(3,379)
Net income	—	—		—		28,733		28,733
BALANCE - March 31, 2023	115,171	$	115	$	970,675	$	12,133	$	982,923
Stock-based compensation cost	—	—		3,758		—		3,758
Issuance of equity awards, net	76	—		—		—		—
Tax withholdings paid for net settlement of equity awards	—	—		(4)		—		(4)
Share repurchases	(2,289)	(2)		(17,468)		—		(17,470)
Excise tax on share repurchases	—	—		(105)		—		(105)
Net income	—	—		—		39,257		39,257
BALANCE - June 30, 2023	112,958	$	113	$	956,856	$	51,390	$	1,008,359


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

Nine Months Ended September 30, 2022
Common Stock
Shares Amount Additional Paid-In Capital Accumulated Deficit Total
BALANCE - January 1, 2022 103,437 $ 103 $ 844,829 $ (18,630) $ 826,302
Stock-based compensation cost — — 11,364 — 11,364
Issuance of equity awards, net 562 1 419 — 420
Tax withholdings paid for net settlement of equity awards — — (2,691) — (2,691)
Net income (loss) — — — 11,817 11,817
BALANCE - March 31, 2022 103,999 $ 104 $ 853,921 $ (6,813) $ 847,212
Stock-based compensation cost — — 3,458 — 3,458
Issuance of equity awards, net 309 — 321 — 321
Tax withholdings paid for net settlement of equity awards — — (1,095) — (1,095)
Net income (loss) — — — (32,860) (32,860)
BALANCE - June 30, 2022 104,308 $ 104 $ 856,605 $ (39,673) $ 817,036
Stock-based compensation cost — — 3,306 — 3,306
Issuance of equity awards, net 118 — 222 — 222
Tax withholdings paid for net settlement of equity awards — — (58) — (58)
Net income (loss) — — — 10,032 10,032
BALANCE - September 30, 2022 104,426 $ 104 $ 860,075 $ (29,641) $ 830,538

Nine Months Ended September 30, 2021
Common Stock
Shares Amount Additional Paid-In Capital Retained Earnings Total
BALANCE - January 1, 2021 100,913 $ 101 $ 835,115 $ 35,555 $ 870,771
Stock-based compensation cost — — 2,487 — 2,487
Issuance of equity awards, net 1,145 1 (1) — —
Tax withholdings paid for net settlement of equity awards — — (5,614) — (5,614)
Net income (loss) — — — (20,375) (20,375)
BALANCE - March 31, 2021 102,058 $ 102 $ 831,987 $ 15,180 $ 847,269
Stock-based compensation cost — — 2,909 — 2,909
Issuance of equity awards, net 1,169 1 (1) — —
Tax withholdings paid for net settlement of equity awards — — (159) — (159)
Proceeds from exercise of stock awards — — 3,235 — 3,235
Net income (loss) — — — (8,511) (8,511)
BALANCE - June 30, 2021 103,227 $ 103 $ 837,971 $ 6,669 $ 844,743
Stock-based compensation cost — — 3,009 — 3,009
Issuance of equity awards, net 33 — — — —
Proceeds from exercise of stock awards — — 130 — 130
Net income (loss) — — — (5,067) (5,067)
BALANCE - September 30, 2021 103,260 $ 103 $ 841,110 $ 1,602 $ 842,815

See notes to condensed consolidated financial statements.

-3-

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

Nine Months Ended September 30,
2022 2021
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) $ (11,012) $ (33,953)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization 93,734 100,253
Impairment expense 57,454 —
Deferred income tax expense (benefit) (1,926) (11,639)
Amortization of deferred debt issuance costs 720 405
Stock-based compensation 18,128 8,405
Provision for credit losses — 282
Loss on disposal of assets 75,240 40,500
Unrealized loss on short-term investment 3,349 —
Non cash income from settlement with equipment manufacturer (2,668) —
Changes in operating assets and liabilities:
Accounts receivable (82,374) (65,244)
Other current assets (29,647) 325
Inventories 6 (747)
Prepaid expenses 2,847 6,027
Accounts payable 7,117 64,237
Accrued and other current liabilities 43,983 408
Net cash provided by operating activities 174,951 109,259
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures (247,164) (87,700)
Proceeds from sale of assets 7,207 2,151
Net cash used in investing activities (239,957) (85,549)
CASH FLOWS FROM FINANCING ACTIVITIES:
Repayments of insurance financing — (5,473)
Payment of debt issuance costs (824) —
Proceeds from exercise of equity awards 963 3,365
Tax withholdings paid for net settlement of equity awards (3,843) (5,773)
Net cash used in financing activities (3,704) (7,881)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS (68,710) 15,829
CASH AND CASH EQUIVALENTS - Beginning of period 111,918 68,772
CASH AND CASH EQUIVALENTS - End of period $ 43,208 $ 84,601


	Six Months Ended June 30,
	2023		2022
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	67,990	$	(21,043)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	103,687		78,973
Impairment expense	—		57,454
Deferred income tax expense	18,897		(4,321)
Amortization of deferred debt issuance costs	140		655
Stock-based compensation	7,294		14,822
Loss on disposal of assets	25,145		22,947
Unrealized loss on short-term investment	3,846		—
Changes in operating assets and liabilities:
Accounts receivable	(35,178)		(53,878)
Other current assets	(983)		561
Inventories	(6,792)		457
Prepaid expenses	(144)		3,343
Accounts payable	(3,160)		(426)
Accrued and other current liabilities	5,769		3,764
Accrued interest	503		—
Net cash provided by operating activities	187,014		103,308
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(223,775)		(144,519)
Proceeds from sale of assets	2,044		2,951
Net cash used in investing activities	(221,731)		(141,568)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	30,000		—
Payment of debt issuance costs	(1,179)		(824)
Proceeds from exercise of equity awards	—		741
Tax withholdings paid for net settlement of equity awards	(3,383)		(3,786)
Share repurchases	(17,470)		—
Net cash provided by (used in) financing activities	7,968		(3,869)
NET DECREASE IN CASH, CASH EQUIVALENTS AND RESTRICTED CASH	(26,749)		(42,129)
CASH, CASH EQUIVALENTS AND RESTRICTED CASH - Beginning of period	88,862		111,918
CASH, CASH EQUIVALENTS AND RESTRICTED CASH - End of period	$	62,113	$	69,789

SUPPLEMENTAL DISCLOSURE OF NON-CASH INVESTING AND FINANCING ACTIVITIES:
Capital expenditures included in accounts payable and accrued liabilities	$	71,080	$	53,108

See notes to condensed consolidated financial statements.

-4-

PROPETRO HOLDING CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Continued)

(In thousands)

(Unaudited)

The following table provides a reconciliation of cash, cash equivalents and restricted cash to amounts reported within the condensed consolidated balance sheets:


	Six Months Ended June 30,
	2023		2022
Summary of cash, cash equivalents and restricted cash
Cash and cash equivalents	$	49,890	$	69,789
Restricted cash	12,223		—
Total cash, cash equivalents and restricted cash — End of period	$	62,113	$	69,789

See notes to condensed consolidated financial statements.

-5-

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~~subsidiaries (the "Company," "we," "us" or "our") have been prepared in accordance with the requirements of the U.S. Securities and Exchange Commission ("SEC") for interim financial information and do not include all of the information and footnotes required by accounting principles generally accepted in the United States of America ("GAAP") for annual financial statements. Those adjustments (which consisted of normal recurring accruals) that are, in the opinion of management, necessary for a fair presentation of the results of the interim periods have been made. Results of operations for such interim periods are not necessarily indicative of the results of operations for a full year due to changes in market conditions and other factors. The condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto for the year ended December 31, ~~2021,~~2022, included in our Form 10-K filed with the SEC (our "Form 10-K").

Revenue Recognition

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

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

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

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

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

Wireline services (including pumpdown) are oil well completion techniques, which are part of the well completion process. Our wireline services utilize equipment with a drum of wireline to deploy perforating guns in the well to perforate the casing, cement, and formation. Once the well is perforated, the well can be fractured. Pumpdown utilizes pressure pumping equipment to pump water into the well to deploy perforating guns attached to wireline through the lateral section of a well. Our wireline contracts with our customers have one performance obligation, which is the contracted total stages, satisfied over time. We recognize revenue over time using a progress output, unit-of-work performed method, which is based on the agreed fixed transaction price and actual stages completed. We believe that recognizing revenue based on actual stages completed accurately depicts how our wireline services are transferred to our customers over time. In addition, certain of our wireline equipment is entitled to daily equipment charges while the equipment is on the customer’s locations. The Company recognizes revenue related to daily equipment charges on a daily basis as the performance obligations are met.

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

~~All Other~~— All other consists of coiled tubing operations, which are downhole well completion/remedial services. The performance obligation for these services has a fixed transaction price which is satisfied at a point-in-time upon completion of the service when control is transferred to the customer. Accordingly, we recognize revenue at a point-in-time, upon completion of the service and transfer of control to the custome~~r. Effective September 1, 2022, we shut down our coiled tubing operations, and disposed of all our coiled tubing assets.~~

~~-5-~~-6-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 - Basis of Presentation (Continued)

All Other— All Other consisted of coiled tubing services, which are complementary downhole well completion/remedial services. The performance obligation for these services had a fixed transaction price which was satisfied at a point-in-time upon completion of the service when control was transferred to the customer. Accordingly, we recognized revenue at a point-in-time, upon completion of the service and transfer of control to the customer. Effective September 1, 2022, we shut down our coiled tubing operations, and disposed of all our coiled tubing assets.

Restricted Cash and Customer Cash Advances

Our restricted cash relates to cash advances received from a customer in connection with our contract with the customer to provide electric hydraulic fracturing equipment and services. The restricted cash will be used to pay for contractually agreed upon expenditures. The cash advances from the customer will be credited towards the customer’s invoice as our revenue performance obligations are met over the contract period. Our restricted cash balances as of June 30, 2023 and December 31, 2022, were $12.2 million and $10.0 million, respectively.

The cash advances received represent contract liabilities in connection with the performance of certain completion services. The cash advance (contract liability) balances, which are included in accrued and other current liabilities in our condensed consolidated balance sheets, were $20.3 million and $10.0 million as of June 30, 2023 and December 31, 2022, respectively. During the six months ended June 30, 2023, we recognized revenue of $2.7 million from the cash advance amount outstanding at the beginning of the period.

Accounts Receivable

Accounts receivables are stated at the amount billed and billable to customers. At ~~September~~June 30, ~~2022,~~2023 and December 31, ~~2021,~~2022, accrued revenue (unbilled receivable) included as part of our accounts receivable was $~~37.1~~54.2 million and $~~19.4~~51.9 million, respectively. At ~~September~~June 30, ~~2022,~~2023, the transaction price allocated to the remaining performance obligation for our partially completed hydraulic fracturing and wireline operations was ~~$42.3~~$83.5 million, which is expected to be completed and recognized as revenue within one month following the current period balance sheet ~~date, in our pressure pumping reportable segment.~~date.

Allowance for Credit Losses

As of ~~September~~June 30, ~~2022,~~2023, the Company had $0.2 million allowance for credit losses. Our allowance for credit losses is based on the evaluation of both our historic ~~loss~~collection experience and the ~~expected impact of any potential deteriorating~~ economic ~~conditions in~~outlook for the oil and gas industry. We evaluated the historic loss experience on our accounts receivable and also considered separately ~~considered~~ customers with receivable balances that ~~could~~may be negatively impacted by current or future economic developments and market conditions. While the Company has not experienced significant credit losses in the past and has not yet seen material adverse 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 or potential~~depressed economic ~~downturn,~~activities, including the potential impact of periodically adjusted borrowing base limits, level of hedged production, or unforeseen well shut-downs may affect the ability of its customers to timely pay receivables when due. Accordingly, in future periods, the Company may revise its estimates of expected credit losses.

The table below shows a summary of allowance for credit losses during the ~~nine~~six months ended ~~September~~June 30, ~~2022:~~2023:


(in thousands)

Balance - January 1, ~~2022~~2023	$	~~217~~419
Provision for credit losses during the period	—
Write-off during the period	— (217)
Balance - ~~September~~June 30, ~~2022~~2023	$	~~217~~202

Reclassification of Prior Period Presentation

Certain reclassifications have been made to prior period amounts to conform to the current period presentation. These reclassifications had no effect on our balance sheet, operating and net income (loss) or cash flows from operating, investing and financing activities.

-7-

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 1 - Basis of Presentation (Continued)

Change in Accounting Estimates

Current trends in hydraulic fracturing equipment operating conditions such as larger pads, changes to job design and increased pumping hours per day have resulted in shorter useful lives for certain critical components that are included in our property and equipment assets. These recent trends necessitated a review of useful lives of our critical components like fluid ends, power ends, hydraulic fracturing units and other components in the first quarter of 2023. We determined that the estimated useful life of fluid ends is now less than one year, resulting in our determination that costs associated with the replacement of these components will no longer be capitalized, but instead recorded in inventories and amortized to cost of services over their estimated useful life. We have also shortened the estimated useful lives of power ends to two years from five years and hydraulic fracturing units to ten years from fifteen years. This change in accounting estimates was made effective January 1, 2023 and accounted for prospectively. The net effect of this change for the three and six months ended June 30, 2023 was a $3.9 million and $7.3 million decrease in net income, or $0.03 and $0.06 per basic and diluted share, respectively.

Additionally, in connection with the review of our power ends estimated useful life, effective January 1, 2023, we are accelerating the depreciation of the remaining book value of power ends that prematurely fail. In 2022, we wrote off the remaining book value of prematurely failed and disposed of power ends to loss on disposal of assets. The amounts included in depreciation in connection with premature failure of power ends and other components during the three and six months ended June 30, 2023 were $11.8 million and $24.3 million, respectively. Furthermore, to conform to current period presentation, we have reclassified the amounts relating to premature failure of power ends previously included in loss on disposal of assets to depreciation expense for prior periods. The amounts reclassified were $9.5 million and $15.7 million, which relate to the three and six months ended June 30, 2022, respectively.

Depreciation and Amortization

Depreciation and amortization comprised of the following:


(in thousands)
	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Depreciation and amortization related to cost of services	$	51,390	$	40,873	$	100,664	$	78,794
Depreciation and amortization related to general and administrative expenses	1,499		96		3,023		179
Total depreciation and amortization	$	52,889	$	40,969	$	103,687	$	78,973

Share Repurchases

All shares of common stock repurchased through the Company's share repurchase program are retired upon repurchase. The Company accounts for the purchase price of repurchased common stock in excess of par value ($0.001 per share of common stock) as a reduction of additional paid-in capital, and will continue to do so until additional paid-in capital is reduced to zero. Thereafter, any excess purchase price will be recorded as a reduction to retained earnings.

Note 2 - Recently Issued Accounting Standards

~~Recently Issued~~There were no recently issued Accounting Standards ~~Adopted in 2022~~

~~In March 2020,~~Updates ("ASU") by the Financial Accounting Standards Board ("FASB") ~~issued ASU No. 2020-04,~~ ~~Reference Rate Reform, which provides temporary optional guidance~~that are expected 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 ashave a ~~benchmark rate are modified. This guidance is effective upon issuance and expires~~material impact on ~~December 31, 2022. Effective January 1, 2022, we adopted this guidance, and the adoption did not materially affect the Company’s~~our condensed consolidated financial statements.

Note 3 - Silvertip Acquisition

On November 1, 2022 (the "Silvertip Acquisition Date"), the Company entered into a purchase and sale agreement with New Silvertip Holdco, LLC, pursuant to which the Company acquired 100% of the outstanding limited liability company interests of Silvertip Completion Services Operating, LLC ("Silvertip"), a wireline services company in the Permian Basin, in exchange for total consideration of $148.1 million (the "Silvertip Purchase Price") consisting of 10.1 million shares of our common stock valued at $106.7 million, $30.0 million of cash, the payoff of $7.2 million of assumed debt, and the payment of $4.1 million of

-8-

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 3 - Silvertip Acquisition (Continued)

certain closing and transaction costs (the "Silvertip Acquisition"). The Silvertip Acquisition positions the Company as a more integrated completions-focused oilfield services provider headquartered in the Permian Basin.

The Company accounted for the Silvertip Acquisition using the acquisition method of accounting. The Silvertip Purchase Price was allocated to the major categories of assets acquired and liabilities assumed based upon their estimated fair value at the Silvertip Acquisition Date. The estimated fair values of certain assets and liabilities, including accounts receivable, require significant judgments and estimates. The measurements of assets acquired and liabilities assumed, are based on inputs that are not observable in the market and thus represent Level 3 inputs.

The following table summarizes the fair value of the consideration transferred in the Silvertip Acquisition and the Silvertip Purchase Price to the fair value of the assets acquired and liabilities assumed (which are included within the accompanying condensed consolidated balance sheets) as of the Silvertip Acquisition Date:


(in thousands)
Total Purchase Consideration:
Cash consideration	$	30,000
Equity consideration	106,736
Debt payments and closing costs	11,320
Total consideration	$	148,056

Cash and cash equivalents	$	2,681
Accounts receivable and unbilled revenue	21,079
Inventories	1,209
Prepaid expenses	2,476
Other current assets	1,059
Property and equipment (1)	52,478
Intangible assets:
Trademark/trade name (2)	10,800
Customer relationships (2)	46,500
Goodwill	23,624
Operating lease right-of-use asset	2,783
Total identifiable assets acquired	164,689
Accounts payable	7,659
Accrued and other current liabilities	6,178
Operating lease liability	2,796
Total liabilities assumed	16,633
Total purchase consideration	$	148,056

(1)Remaining useful lives ranging from less than one to 22 years

(2)Definite lived intangibles with amortization period of 10 years.

The goodwill arising from the Silvertip Acquisition is attributable to the expected operational synergies resulting from our integrated service offerings. The goodwill arising from the Silvertip Acquisition has been allocated to our wireline operations and is included in our wireline operating segment.

Note 34 - Fair Value ~~Measurement~~Measurements

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

-9-

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 4 - Fair Value Measurements (Continued)

requiring that the most observable inputs be used, when available. Observable inputs are inputs that market participants would use in pricing the asset or liability developed based on market data obtained from sources independent of the Company. Unobservable inputs are inputs that reflect the Company's assumptions about the assumptions other market participants would use in pricing the asset or liability developed based on the best information available in the circumstances. The hierarchy is broken down into three levels based on the observability of inputs as follows:

Level 1 — Valuations based on quoted prices in active markets for identical assets or liabilities that the Company has the ability to access. Valuation adjustments and block discounts are not applied to Level 1 instruments. Since valuations are based on

~~-6-~~

~~PROPETRO HOLDING CORP.~~

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

~~(Unaudited)~~

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

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

The fair values of cash, cash equivalents and restricted cash, accounts receivable, accounts payable, accrued and other current liabilities, and long-term debt are estimated to be approximately equivalent to carrying amounts as of June 30, 2023 and December 31, 2022 and have been excluded from the table below.

Assets measured at fair value on a recurring basis ~~as of September 30, 2022~~ 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)
September 30, 2022:
Short-term investment $ 8,503 $ 8,503 $ — $ — $ (3,349)


(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, 2023:
Short-term investment	$	6,437	$	6,437	$	—	$	—	$	(3,846)
December 31, 2022:
Short-term investment	$	10,283	$	10,283	$	—	$	—	$	(1,570)

Short-term investment— On September 1, 2022, the Company received ~~2,616,460~~2.6 million common shares of ~~Step~~STEP Energy Services ~~Inc.~~Ltd. ("STEP") with an estimated fair value of ~~$11.9~~$11.8 million as part of the consideration for the sale of our coiled tubing assets to STEP. The shares were treated as an investment in equity securities measured at fair value using Level 1 inputs based on observable prices on the Toronto Stock Exchange and are shown under current assets in our condensed consolidated balance sheets. As of ~~September~~June 30, ~~2022,~~2023, the fair value of the short-term investment was estimated at ~~$8.5 million, and the~~$6.4 million. The unrealized loss resulting from the fluctuation in stock price was ~~$3.3 million.~~$0.1 million and $3.9 million during the three and six months ended June 30, 2023, respectively. Included in the unrealized loss was a ~~loss~~gain of ~~$0.4~~$0.1 million resulting from non-cash foreign currency translation during the three and six months ended June 30, 2023. . The unrealized ~~losses~~loss resulting from stock price fluctuation and the unrealized gain resulting from non-cash foreign currency translation are included in other income (expense) in our condensed consolidated statements of operations.

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

~~Assets Measured at Fair Value on a Nonrecurring Basis~~

~~On September 21, 2022, the Company received equipment inventory from the manufacturer of~~ ~~DuraStim®~~ ~~hydraulic fracturing equipment~~ ~~in connection with its settlement of warranty claims for the~~ ~~DuraStim®~~ ~~hydraulic fracturing equipment acquired from the manufacturer. The fair value of this equipment inventory received from the manufacturer was estimated to be~~ $2.7 million. The estimated fair value was determined using the cost approach, which represents a Level 3 in the fair value measurement hierarchy. Our fair value estimate required us to use significant unobservable inputs, including a third party valuation and assumptions related to replacement cost, among others. Accordingly, we recorded non cash income of $2.7 million, which is presented within other income (expense) in ~~our condensed consolidated statements of operations, and the equipment inventory received included as part of our property and equipment in our condensed consolidated balance sheets. As ofSeptember 30, 2022, the remaining carrying value for the equipment inventory was $2.7 million~~.

~~-7-~~-10-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 34 - Fair Value ~~Measurement~~Measurements (Continued)

Assets Measured at Fair Value on a Nonrecurring Basis

Certain assets and liabilities are measured at fair value on a nonrecurring basis. These items are not measured at fair value on an ongoing basis but may be subject to fair value adjustments in certain circumstances. These assets and liabilities include those acquired through the Silvertip Acquisition, which are required to be measured at fair value on the acquisition date according to the FASB Accounting Standards Codification ("ASC") Topic 805, Business Combinations.

Whenever events or circumstances indicate that the carrying value of long-lived assets may not be recoverable, the Company reviews the carrying value of long‑lived assets, such as property and equipment and other assets to determine if they are recoverable. If any long‑lived assets are determined to be unrecoverable, an impairment expense is recorded in the period. No impairment of property and equipment was recorded during the ~~three~~six months ended ~~September~~June 30, ~~2022 and 2021.~~ ~~For the nine months ended~~ ~~September 30, 2022, we~~2023. We recorded impairment expense of approximately $57.5 million during the six months ended June 30, 2022.

As of June 30, 2023 and December 31, 2022, our goodwill carrying value was $23.6 million and $23.6 million, respectively. There were no additions to goodwill during the three and six months ended June 30, 2023 and 2022. The wireline operating segment is the only segment with goodwill at June 30, 2023 and December 31, 2022. There were no goodwill impairment losses during the three and six months ended June 30, 2023 and 2022.We conducted our annual impairment test of goodwill in ~~connection~~accordance with ASC 850, Intangibles—Goodwill and Other, as of December 31, 2022 and determined that no impairment to the carrying value of goodwill for our ~~electric pressure pumping technology driven~~ ~~DuraStim®~~ ~~hydraulic fracturing pumps that did not meet the manufacturer's specifications or our expectations.~~ reporting unit (wireline operating segment) was required.

Note 45 - Intangible Assets

Intangible assets consist of customer relationships and trademark/trade name. Intangible assets are amortized on a straight‑line basis with a useful life of ten years. Amortization expense included in net income for the three and six months ended June 30, 2023 was $1.4 million and $2.9 million, respectively. There was no amortization expense during the three and six months ended June 30, 2022. The Company’s intangible assets subject to amortization consisted of the following:


(in thousands)
	June 30, 2023		December 31, 2022
Intangible assets acquired:
Trademark/trade name	$	10,800	$	10,800
Customer relationships	46,500		46,500
Total intangible assets acquired	57,300		57,300

Accumulated amortization:
Trademark/trade name	(720)		(180)
Customer relationships	(3,100)		(775)
Total accumulated amortization	(3,820)		(955)

Intangible assets — net	$	53,480	$	56,345

The average amortization period for our remaining intangible assets is approximately 9.3 years. Estimated remaining amortization expense for each of the subsequent fiscal years is expected to be as follows:


(in thousands)
Year	Estimated future amortization expense
2023	$	2,865
2024	5,730
2025	5,730
2026	5,730
2027 and beyond	33,425
Total	$	53,480

-11-

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 6 - Long-Term Debt

Asset-Based Loan ("ABL") Credit Facility

Our revolving credit facility, as amended and restated in ~~2018,~~April 2022, prior to giving effect to the amendment to the revolving credit facility in June 2023, had a total borrowing capacity of ~~$300.0 million (subject to the borrowing base limit), with a maturity date of December 19, 2023.~~$150.0 million. The revolving credit facility had a borrowing base of 85% to 90%, depending on the credit ratings of our accounts receivable counterparties, of monthly eligible accounts receivable less customary ~~reserves, as redetermined monthly.~~reserves. The revolving credit facility included a springing fixed charge coverage ratio to apply when excess availability was less than the greater of (i) 10% of the lesser of the facility size or the borrowing base or (ii) ~~$22.5~~$10.0 million. ~~Borrowings under this~~Under the revolving credit facility ~~accrued interest based on a three-tier pricing grid tied to availability, and~~ we had the option to elect for loans to be based on either LIBOR or base rate, plus the applicable margin, which ranged from 1.75% to 2.25% for LIBOR loans and 0.75% to 1.25% for base rate loans, with a LIBOR floor of zero.

Effective April 13, 2022, the Company entered into an amendment and restatement of its revolving credit facility (as amended and restated, "ABL Credit Facility"). The ABL Credit Facility decreased the borrowing capacity to $150.0 million (subject to the Borrowing Base (as defined below) limit), with the maturity date extended to April 13, 2027. The ABL Credit Facility has a borrowing base of 85% to 90%, depending on the credit ratings of our accounts receivable counterparties, of monthly eligible accounts receivable less customary reserves (the "Borrowing Base"), as redetermined monthly. The Borrowing Base as of September 30, 2022, was approximately $116.4 million. The ABL Credit Facility includes a springing fixed charge coverage ratio to apply when excess availability is less than the greater of (i) 10% of the lesser of the facility size or the Borrowing Base or (ii) $10.0 million. Under this facility we arewere 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.

Effective June 2, 2023, the Company entered into an amendment to its amended and restated revolving credit facility (the revolving credit facility, as amended and restated in April 2022, as amended in June 2023 and as may be amended further, "ABL Credit Facility"). The amendment increased the borrowing capacity under the ABL Credit Facility to $225.0 million (subject to the Borrowing Base (as defined below) limit), and extended the maturity date to June 2, 2028. The ABL Credit Facility has a borrowing base of the sum of 85% to 90% of monthly eligible accounts receivable and 80% of eligible unbilled accounts (up to a maximum of 25% of the Borrowing Base) less customary reserves (the "Borrowing Base"), in each case, depending on the credit ratings of our accounts receivable counterparties, as redetermined monthly. The Borrowing Base as of June 30, 2023, was approximately $173.5 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) $15.0 million. Under the ABL Credit 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 or indebtedness, changes in the nature of our business, mergers and other fundamental changes, disposal of assets, investments and restricted payments, amendments to our organizational documents or accounting policies, prepayments of certain debt, dividends, transactions with affiliates, and certain other activities. Borrowings under the ABL Credit Facility are secured by a first priority lien and security interest in substantially all assets of the Company.

Borrowings under the ABL Credit Facility accrue interest based on a three-tier pricing grid tied to availability, and we may elect for loans to be based on either the Secured Overnight Financing Rate ("SOFR") or the base rate, plus the applicable margin, which ranges from ~~1.50%~~1.75% to ~~2.00%~~2.25% for SOFR loans and ~~0.50%~~0.75% to ~~1.00%~~1.25% for base rate loans. For the six months endedJune 30, 2023, the weighted average interest rate on our outstanding borrowings under the ABL Credit Facility was 6.21%.

The loan origination costs relating to the ABL Credit Facility are classified as an asset in ~~our~~the condensed consolidated balance ~~sheet. There were~~ ~~no borrowings~~ ~~under the ABL credit facility or our previous revolving credit facility as~~sheets. As of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021.~~2022, we had borrowings outstanding under our ABL Credit Facility of $60.0 million and $30.0 million, respectively.

Note 57 - Reportable Segment Information

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

On September 1, 2022, the Company shut down its coiled tubing operations and disposed of its coiled tubing assets ~~(included in the "all other" category)~~ to ~~a subsidiary of~~ STEP as part of a strategic ~~repositioning.~~repositioning, and recorded a loss on disposal of $13.8 million. The divestiture of our coiled tubing assets did not qualify for presentation and disclosure as discontinued operations, and accordingly, we have recorded the resulting loss ~~of approximately~~ ~~$13.8 million~~ ~~as part of our loss on~~from the disposal of assets in our condensed consolidated statement of operations. ~~We received approximately $2.8 million in cash and 2,616,460 common shares of STEP valued at $11.9 million as consideration for~~Following the ~~coiled tubing assets, for total consideration of $14.6 million. The~~ divestiture of our coiled tubing ~~assets~~operations, which were historically included in the "All Other" category, and the Silvertip Acquisition, which resulted in ~~a reduction~~our new wireline operations in ~~the number of our current~~2022, we have three operating segments. All three remaining operating segments ~~to two. The change in the number of~~are now aggregated into Completion Services, which is our ~~operating segments did not impact our~~only reportable ~~segment information reported for the~~ ~~three and nine months ended September 30, 2022 and 2021.~~segment.

~~-8-~~-12-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 57 - Reportable Segment Information (Continued)

In accordance with ~~the~~ ~~FASB Accounting Standards Codification~~ ~~("ASC")~~ASC 280—Segment Reporting, the Company has one reportable segment ~~(pressure pumping)~~(Completion Services) comprised of the hydraulic fracturing, cementing and ~~cementing~~wireline operating segments. ~~Our~~The Silvertip Acquisition which resulted in the addition of a new wireline operating segment, and the disposal of our coiled tubing ~~results of~~ operations ~~prior~~(previously included in the "All Other" category), collectively resulted in a change to the ~~divestiture~~structure and composition of our reportable segment and "All Other" category. Our previous Pressure Pumping reportable segment is now renamed "Completion Services" because of the inclusion of the new wireline completion services. In addition, we have reclassified all our corporate ~~administrative expense~~overhead costs (inclusive of ~~our total~~ income ~~tax expense (benefit), other (income) and expense~~taxes and interest expense) ~~are~~previously included in the ~~"all other"~~"All Other" category to the Completion Services reportable segment. As a result of the change in the ~~table below.~~structure and composition of our reportable segment, we have reclassified the presentation of our segment disclosure for the three and six months ended June 30, 2022 to include corporate costs in our Completion Services reportable segment to make this period comparable to the three and six months ended June 30, 2023. Total corporate administrative expense for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 was ~~$20.4~~$26.9 million and ~~$45.4~~$52.2 million,, respectively. Total corporate administrative expense for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021~~2022 was ~~$13.5~~$7.7 million and ~~$25.1~~$25.0 million, respectively.

~~Our hydraulic fracturing~~A breakout of our Completion Services revenue by operating segment ~~revenue approximated 91.7% and 92.7% of our~~for the ~~pressure pumping revenue during the~~ three and ~~nine~~six months ended ~~September~~June 30, 2023 and 2022 ~~respectively. During the three and nine~~is presented below: ~~months ended September 30, 2021, our hydraulic fracturing operating segment revenue approximated 93.4% and 93.5% of~~ ~~our pressure pumping revenue, respectively.~~


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Hydraulic fracturing revenue	78.9	%	92.9	%	78.9	%	93.2	%
Cementing revenue	6.4	%	7.1	%	6.4	%	6.8	%
Wireline revenue	14.7	%	—	%	14.7	%	—	%
Total Completion Services revenue	100.0	%	100.0	%	100.0	%	100.0	%

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, retention bonuses, severance and related expense, impairment expense, (gain)/loss on disposal of assets and other unusual or nonrecurring expenses or (income)).

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

Three Months Ended September 30, 2022
Pressure Pumping All Other Total
Service revenue $ 330,780 $ 2,234 $ 333,014
Adjusted EBITDA $ 102,550 $ (12,550) $ 90,000
Depreciation and amortization $ 29,736 $ 681 $ 30,417
Capital expenditures $ 112,865 $ 2,258 $ 115,123
Total assets at September 30, 2022 $ 1,091,796 $ 51,810 $ 1,143,606

Three Months Ended September 30, 2021
Pressure Pumping All Other Total
Service revenue $ 245,641 $ 4,458 $ 250,099
Adjusted EBITDA $ 53,975 $ (11,877) $ 42,098
Depreciation and amortization $ 32,536 $ 995 $ 33,531
Capital expenditures $ 52,904 $ 300 $ 53,204
Total assets December 31, 2021 $ 1,023,037 $ 38,199 $ 1,061,236

Nine Months Ended September 30, 2022
Pressure Pumping All Other Total
Service revenue $ 917,336 $ 13,440 $ 930,776
Adjusted EBITDA $ 265,835 $ (33,355) $ 232,480
Depreciation and amortization $ 91,194 $ 2,540 $ 93,734
Capital expenditures $ 267,638 $ 8,294 $ 275,932
Total assets at September 30, 2022 $ 1,091,796 $ 51,810 $ 1,143,606

~~-9-~~-13-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 57 - Reportable Segment Information (Continued)

Nine Months Ended September 30, 2021
Pressure Pumping All Other Total
Service revenue $ 617,293 $ 11,151 $ 628,444
Adjusted EBITDA $ 132,673 $ (34,866) $ 97,807
Depreciation and amortization $ 97,307 $ 2,946 $ 100,253
Capital expenditures $ 113,670 $ 2,634 $ 116,304
Total assets December 31, 2021 $ 1,023,037 $ 38,199 $ 1,061,236

~~Reconciliation~~A reconciliation from segment level financial information to the consolidated statements of ~~net income (loss) to adjusted EBITDA~~operations is provided in the table below (in thousands):

Three Months Ended September 30, 2022
Pressure Pumping All Other Total
Net income (loss) $ 46,805 $ (36,773) $ 10,032
Depreciation and amortization 29,736 681 30,417
Interest expense — 237 237
Income tax expense — 2,768 2,768
Loss (gain) on disposal of assets 22,850 13,786 36,636
Stock-based compensation — 3,306 3,306
Other (income) expense (3)
(2,668) 3,284 616
Other general and administrative expense (1)
4,775 145 4,920
Severance expense 1,052 16 1,068
Adjusted EBITDA $ 102,550 $ (12,550) $ 90,000
Three Months Ended September 30, 2021
Pressure Pumping All Other Total
Net income (loss) $ 9,058 $ (14,125) $ (5,067)
Depreciation and amortization 32,536 995 33,531
Interest expense — 143 143
Income tax benefit — (1,279) (1,279)
Loss on disposal of assets 12,381 43 12,424
Stock-based compensation — 3,009 3,009
Other expense — 309 309
Other general and administrative expense, (net) (1)
— (972) (972)
Adjusted EBITDA $ 53,975 $ (11,877) $ 42,098


	Three Months Ended June 30, 2023
	Completion Services		All Other		Total
Service revenue	$	435,249	$	—	$	435,249
Adjusted EBITDA	$	112,813	$	—	$	112,813
Depreciation and amortization	$	52,889	$	—	$	52,889
Capital expenditures	$	115,233	$	—	$	115,233
Goodwill at June 30, 2023	$	23,624	$	—	$	23,624
Total assets at June 30, 2023	$	1,433,379	$	—	$	1,433,379


	Three Months Ended June 30, 2022
	Completion Services		All Other		Total
Service revenue	$	309,445	$	5,638	$	315,083
Adjusted EBITDA	$	75,842	$	105	$	75,947
Depreciation and amortization	$	40,131	$	838	$	40,969
Capital expenditures	$	88,842	$	239	$	89,081
Total assets December 31, 2022	$	1,335,501	$	285	$	1,335,786


	Six Months Ended June 30, 2023
	Completion Services		All Other		Total
Service revenue	$	858,819	$	—	$	858,819
Adjusted EBITDA	$	231,978	$	—	$	231,978
Depreciation and amortization	$	103,687	$	—	$	103,687
Capital expenditures	$	212,403	$	—	$	212,403
Goodwill at June 30, 2023	$	23,624	$	—	$	23,624
Total assets June 30, 2023	$	1,433,379	$	—	$	1,433,379


	Six Months Ended June 30, 2022
	Completion Services		All Other		Total
Service revenue	$	586,557	$	11,206	$	597,763
Adjusted EBITDA	$	141,814	$	666	$	142,480
Depreciation and amortization	$	77,293	$	1,680	$	78,973
Capital expenditures	$	160,444	$	365	$	160,809
Total assets December 31, 2022	$	1,335,501	$	285	$	1,335,786

~~-10-~~-14-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 57 - Reportable Segment Information (Continued)

Nine Months Ended September 30, 2022
Pressure Pumping All Other Total
Net income (loss) $ 51,782 $ (62,794) $ (11,012)
Depreciation and amortization 91,194 2,540 93,734
Impairment expense 57,454 — 57,454
Interest expense — 1,040 1,040
Income tax benefit — (1,164) (1,164)
Loss (gain) on disposal of assets 61,952 13,288 75,240
Stock-based compensation — 18,128 18,128
Other income (2) (3)
(2,668) (7,081) (9,749)
Other general and administrative expense (1)
5,060 2,651 7,711
Severance expense 1,061 37 1,098
Adjusted EBITDA $ 265,835 $ (33,355) $ 232,480
Nine Months Ended September 30, 2021
Pressure Pumping All Other Total
Net income (loss) $ (5,426) $ (28,527) $ (33,953)
Depreciation and amortization 97,307 2,946 100,253
Interest expense — 477 477
Income tax benefit — (11,639) (11,639)
Loss (gain) on disposal of assets 40,792 (292) 40,500
Stock-based compensation — 8,405 8,405
Other income — (1,178) (1,178)
Other general and administrative expense, (net) (1)
— (5,670) (5,670)
Severance expense — 612 612
Adjusted EBITDA $ 132,673 $ (34,866) $ 97,807
Reconciliation of net income (loss) to adjusted EBITDA (in thousands):


	Three Months Ended June 30, 2023
	Completion Services		All Other		Total
Net income	$	39,257	$	—	$	39,257
Depreciation and amortization	52,889		—		52,889
Interest expense	1,180		—		1,180
Income tax expense	12,118		—		12,118
Loss on disposal of assets	3,065		—		3,065
Stock-based compensation	3,758		—		3,758
Other income (1)	(72)		—		(72)
Other general and administrative expense, (net) (2)	263		—		263
Retention bonus and severance expense	355		—		355
Adjusted EBITDA	$	112,813	$	—	$	112,813

	Three Months Ended June 30, 2022
	Completion Services		All Other		Total
Net loss	$	(32,119)	$	(741)	$	(32,860)
Depreciation and amortization	40,131		838		40,969
Impairment expense	57,454		—		57,454
Interest expense	669		—		669
Income tax benefit	(8,069)		—		(8,069)
Loss on disposal of assets	12,970		8		12,978
Stock-based compensation	3,458		—		3,458
Other income	(6)		—		(6)
Other general and administrative expense, (net) (2)	1,345		—		1,345
Severance expense	9		—		9
Adjusted EBITDA	$	75,842	$	105	$	75,947

-15-

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 7 - Reportable Segment Information (Continued)


	Six Months Ended June 30, 2023
	Completion Services		All Other		Total
Net income	$	67,990	$	—	$	67,990
Depreciation and amortization	103,687		—		103,687
Interest expense	1,847		—		1,847
Income tax expense	20,474		—		20,474
Loss on disposal of assets	25,145		—		25,145
Stock-based compensation	7,294		—		7,294
Other expense (1)	3,632		—		3,632
Other general and administrative expense, (net) (2)	1,209		—		1,209
Severance expense	700		—		700
Adjusted EBITDA	$	231,978	$	—	$	231,978

	Six Months Ended June 30, 2022
	Completion Services		All Other		Total
Net loss	$	(20,036)	$	(1,007)	$	(21,043)
Depreciation and amortization	77,293		1,680		78,973
Impairment expense	57,454		—		57,454
Interest expense	803		—		803
Income tax benefit	(3,932)		—		(3,932)
Loss (gain) on disposal of assets	22,954		(7)		22,947
Stock-based compensation	14,822		—		14,822
Other income (3)	(10,364)		—		(10,364)
Other general and administrative expense, (net) (2)	2,791		—		2,791
Severance expense	29		—		29
Adjusted EBITDA	$	141,814	$	666	$	142,480

(1)Includes unrealized loss on short-term investment of $0.1 million and $3.9 million for the three and six months ended June 30, 2023, respectively.

(2)Other general and administrative expense, (net of reimbursement from insurance carriers) primarily relates to nonrecurring professional fees paid to external consultants in connection with our audit committee review, SEC investigation, shareholder litigation, legal settlement to a vendor and other legal matters, net of insurance recoveries. During the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023, we received reimbursement of approximately ~~$3.4 million~~$0 and ~~$6.9~~$0.3 million, respectively, from our insurance carriers in connection with the SEC investigation and shareholder litigation. During the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, we received reimbursement of approximately ~~$1.4~~$2.4 million and ~~$8.1~~$3.5 million, ~~respectively.~~respectively, from our insurance carriers in connection with the SEC investigation and shareholder litigation. See "Note 13 - Commitments and Contingencies—Contingent Liabilities—Legal Matters" for further information.

~~(2)~~(3)Includes a $10.7 million of net tax refund (net of advisory fees) received in March 2022 from the Texas Comptroller of Public Accounts in connection with limited sales, excise and use tax ~~beginning~~audit of the period July 1, 2015 through December 31, 2018.

~~(3)~~

Includes $2.7 million non cash income from fixed asset inventory received as part of a settlement of warranty claims with an equipment manufacturer and a $3.3 million unrealized loss on short-term investment.

~~-11-~~-16-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 68 - Net Income (Loss) Per Share

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

The table below shows the calculations for the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022 (in thousands, except for per share data):


		Three Months Ended September 30,					Three Months Ended June 30,
		2022		2021			2023		2022
Numerator (both basic and diluted)	Numerator (both basic and diluted)					Numerator (both basic and diluted)
Net income (loss) relevant to common stockholders	Net income (loss) relevant to common stockholders	$	10,032	$	(5,067)	Net income (loss) relevant to common stockholders	$	39,257	$	(32,860)

Denominator	Denominator					Denominator
Denominator for basic income (loss) per share		104,372		103,257
Denominator for basic income per share						Denominator for basic income per share	114,737		104,236
Dilutive effect of stock options	Dilutive effect of stock options	28		—		Dilutive effect of stock options	—		—
Dilutive effect of performance share units	Dilutive effect of performance share units	498		—		Dilutive effect of performance share units	—		—
Dilutive effect of restricted stock units	Dilutive effect of restricted stock units	172		—		Dilutive effect of restricted stock units	59		—
Denominator for diluted income (loss) per share		105,070		103,257
Denominator for diluted income per share						Denominator for diluted income per share	114,796		104,236

Basic income (loss) per common share	Basic income (loss) per common share	$	0.10	$	(0.05)	Basic income (loss) per common share	$	0.34	$	(0.32)
Diluted income (loss) per common share	Diluted income (loss) per common share	$	0.10	$	(0.05)	Diluted income (loss) per common share	$	0.34	$	(0.32)


		Nine Months Ended September 30,					Six Months Ended June 30,
		2022		2021			2023		2022
Numerator (both basic and diluted)	Numerator (both basic and diluted)					Numerator (both basic and diluted)
Net income (loss) relevant to common stockholders	Net income (loss) relevant to common stockholders	$	(11,012)	$	(33,953)	Net income (loss) relevant to common stockholders	$	67,990	$	(21,043)

Denominator	Denominator					Denominator
Denominator for basic income (loss) per share		104,100		102,408
Denominator for basic income per share						Denominator for basic income per share	114,809		103,961
Dilutive effect of stock options	Dilutive effect of stock options	—		—		Dilutive effect of stock options	—		—
Dilutive effect of performance share units	Dilutive effect of performance share units	—		—		Dilutive effect of performance share units	84		—
Dilutive effect of restricted stock units	Dilutive effect of restricted stock units	—		—		Dilutive effect of restricted stock units	209		—
Denominator for diluted income (loss) per share		104,100		102,408
Denominator for diluted income per share						Denominator for diluted income per share	115,102		103,961

Basic income (loss) per share		$	(0.11)	$	(0.33)
Diluted income (loss) per share		$	(0.11)	$	(0.33)
Basic income (loss) per common share						Basic income (loss) per common share	$	0.59	$	(0.20)
Diluted income (loss) per common share						Diluted income (loss) per common share	$	0.59	$	(0.20)

As shown in the table below, the following stock options, restricted stock units and performance stock units have not been included in the calculation of diluted income per common share for the three and six months ended June 30, 2023 and 2022 because they will be anti-dilutive to the calculation of diluted net income per common share:

~~-12-~~-17-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 68 - Net Income (Loss) Per Share (Continued)

~~As shown~~


(in thousands)	Three Months Ended June 30,
	2023	2022
Stock options	341	587
Restricted stock units	2,007	1,207
Performance stock units	—	1,788
Total	2,348	3,582


(in thousands)	Six Months Ended June 30,
	2023	2022
Stock options	383	587
Restricted stock units	1,317	1,207
Performance stock units	—	1,788
Total	1,700	3,582

Note 9 - Share Repurchase Program

On May 17, 2023, the Company's board of directors (the "Board") authorized and the Company announced a share repurchase program that allows the Company to repurchase up to $100 million of the Company's common stock beginning immediately and continuing through and including May 31, 2024. The shares may be repurchased from time to time in open market transactions, block trades, accelerated share repurchases, privately negotiated transactions, derivative transactions or otherwise, certain of which may be made pursuant to a trading plan meeting the ~~table below,~~requirements of Rule 10b5-1 under the f~~ollowing~~Exchange Act, in compliance with applicable state and federal securities laws. The timing, as well as the number and value of shares repurchased under the program, will be determined by the Company at its discretion and will depend on a variety of factors, including management's assessment of the intrinsic value of the Company's common stock, ~~options, restricted~~the market price of the Company's common stock, ~~units~~general market and ~~performance~~economic conditions, available liquidity, compliance with the Company's debt and other agreements, applicable legal requirements, and other considerations. The Company is not obligated to purchase any shares under the repurchase program, and the program may be suspended, modified, or discontinued at any time without prior notice. The Company expects to fund the repurchases using cash on hand and expected free cash flow to be generated through May 2024. The Inflation Reduction Act of 2022 (the "IRA 2022") provides for, among other things, the imposition of a new 1% U.S. federal excise tax on certain repurchases of stock ~~units outstanding~~by publicly traded U.S. corporations such as us after December 31, 2022. Accordingly, the excise tax will apply to our share repurchase program in 2023 and in subsequent taxable years.

All shares of common stock repurchased under the share repurchase program are canceled and retired upon repurchase. The Company accounts for the purchase price of repurchased shares of common stock in excess of par value ($0.001 per share of common stock) as a reduction of additional-paid-in capital, and will continue to do so until additional paid-in-capital is reduced to zero. Thereafter, any excess purchase price will be recorded as a reduction to retained earnings. During the three months ended June 30, 2023, the Company paid an aggregate of $17.5 million, an average price per share of $7.63 including commissions, for share repurchases under the share repurchase program. The Company has accrued $0.1 million in respect of the IRA 2022 repurchase excise tax as of ~~September~~June 30, ~~2022, have not been included in~~2023. As of June 30, 2023, $82.5 million remained authorized for future repurchases of common stock under the calculation of diluted income (loss) per common share for the three and nine months ended September 30, 2022 and 2021 because they will be anti-dilutive to the calculation of diluted net income (loss) per common share:

(In thousands) Three Months Ended September 30,
2022 2021
Stock options 488 962
Restricted stock units 615 1,435
Performance stock units — 1,586
Total 1,103 3,983

(In thousands) Nine Months Ended September 30,
2022 2021
Stock options 488 962
Restricted stock units 1,189 1,435
Performance stock units 1,758 1,586
Total 3,435 3,983
repurchase program.

Note 710 - Stock-Based Compensation

Stock Options

There were no new stock option grants during the ~~nine~~six months ended ~~September~~June 30, ~~2022.~~2023. As of ~~September~~June 30, ~~2022, there~~2023, there was no aggregate intrinsic value for our ~~outstanding~~outstanding or exercisable stock options because the closing stock price as of ~~September~~June 30, ~~2022~~2023 was below the cost to exercise these options. ~~The aggregate intrinsic value for the exercised~~No stock options were exercised during the ~~nine~~six months ended ~~September~~June 30, ~~2022 was approximately $2.6 million.~~2023. The weighted average remaining ~~exercise period~~contractual term for ~~both~~ the outstanding and exercisable stock options as of ~~September~~June 30, ~~2022~~2023 was approximately ~~2.2~~2.9 years.

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

Number of Shares Weighted
Average
Exercise
Price
Outstanding at January 1, 2022 798 $ 9.77
Granted — $ —
Exercised (310) $ 3.11
Forfeited — $ —
Expired — $ —
Outstanding at September 30, 2022 488 $ 14.00
Exercisable at September 30, 2022 488 $ 14.00

~~-13-~~-18-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 710 - Stock-Based Compensation (Continued)

A summary of the stock option activity for the six months ended June 30, 2023 is presented below (in thousands, except for weighted average price):


	Number of Shares	Weighted Average Exercise Price
Outstanding at January 1, 2023	488	$	14.00
Granted	—	$	—
Exercised	—	$	—
Forfeited	—	$	—
Expired	(246)	$	14.00
Outstanding at June 30, 2023	242	$	14.00
Exercisable at June 30, 2023	242	$	14.00

Restricted Stock Units

During the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, we granted ~~680,946~~1,072,575 restricted stock units ("RSUs") to employees, officers and directors pursuant to the ProPetro Holding Corp. 2020 Long Term Incentive Plan (the "2020 Incentive Plan"), which generally vest ratably over a three-year vesting period, in the case of awards to employees and officers, and generally vest in full after one year, in the case of awards to directors. RSUs are subject to restrictions on transfer and are generally subject to a risk of forfeiture if the award recipient ceases to be an employee or director of the Company prior to vesting of the award. Each RSU represents the right to receive one share of common stock. The grant date fair value of the RSUs is based on the closing share price of our common stock on the date of grant. As of ~~September~~June 30, ~~2022,~~2023, the total unrecognized compensation expense for all RSUs was approximately $~~9.1~~14.4 million, and is expected to be recognized over a weighted average period of approximately ~~1.8~~2.0 years.

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

The following table summarizes RSUs activity during the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 (in thousands, except for ~~weighted average~~ fair value):


		Number of Shares	Weighted Average Grant Date Fair Value			Number of Shares	Weighted Average Grant Date Fair Value
Outstanding at January 1, 2022		1,413	$	9.19
Outstanding at January 1, 2023					Outstanding at January 1, 2023	1,268	$	10.91
Granted	Granted	681	$	12.31	Granted	1,073	$	9.32
Vested	Vested	(845)	$	9.20	Vested	(511)	$	10.88
Forfeited	Forfeited	(60)	$	11.04	Forfeited	(55)	$	10.49
Canceled	Canceled	—	$	—	Canceled	—	$	—
Outstanding at September 30, 2022		1,189	$	10.88
Outstanding at June 30, 2023					Outstanding at June 30, 2023	1,775	$	9.97

Performance Share Units

During the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, we granted ~~327,939~~454,788 performance share units ("PSUs") to certain key employees and officers as new awards under the 2020 Incentive Plan. Each PSU earned represents the right to receive either one share of common stock or, as determined by the 2020 Incentive Plan administrator in its sole discretion, a cash amount equal to fair market value of one share of common stock or amount of cash on the day immediately preceding the settlement date. The actual number of shares of common stock that may be issued under the PSUs ranges from 0% up to a maximum of 200% of the target number of PSUs granted to the participant, based on our total shareholder return ("TSR") relative to a designated peer group, generally at the end of a three year period. In addition to the TSR conditions, vesting of the PSUs is generally subject to the recipient’s continued employment through the end of the applicable performance period. Compensation expense is recorded ratably over the corresponding requisite service period. The grant date fair value of PSUs is determined using a Monte Carlo probability model. Grant recipients do not have any shareholder rights until performance relative to the peer group has been determined following the completion of the performance period and shares have been issued.

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

~~-14-~~-19-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 710 - Stock-Based Compensation (Continued)

The following table summarizes information about PSUs activity during the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 (in thousands, except for weighted average fair value):


Period Granted	Period Granted	Target Shares Outstanding at January 1, 2022		Target Shares Granted		Target Shares Vested		Target Shares Forfeited		Target Shares Outstanding at September 30, 2022		Period Granted	Target Shares Outstanding at January 1, 2023		Target Shares Granted		Target Shares Vested		Target Shares Forfeited		Target Shares Outstanding at June 30, 2023
2019		126		—		(126)		—		—
2020	2020	809		—		—		—		809		2020	809		—		(493)		(315)		—
2021	2021	651		—		—		(18)		632		2021	632		—		—		—		632
2022	2022	—		328		—		(12)		316		2022	316		—		—		—		316
2023												2023	—		455		—		—		455
Total	Total	1,586		328		(126)		(30)		1,757		Total	1,757		455		(493)		(315)		1,403
Weighted Average FV Per Share	Weighted Average FV Per Share	$	12.48	$	19.99	$	27.49	$	17.19	$	12.72	Weighted Average FV Per Share	$	12.72	$	14.40	$	8.30	$	8.30	$	15.81

The total stock-based compensation expense for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021~~2022 for all stock awards was ~~$18.1~~$7.3 million and ~~$8.4~~$14.8 million,, respectively, and the associated tax benefit related thereto was $1.5 million and $3.1 million, respectively. The total unrecognized stock-based compensation expense as of ~~September~~June 30, ~~2022~~2023 was approximately $~~18.7~~24.5 million, and is expected to be recognized over a weighted average period of approximately 1.8 years.

Note 811 - Related-Party Transactions

Operations and Maintenance Yards

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

Pioneer

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

On October 31, 2022, we entered into two pressure pumping services agreements (the "Fleet One Agreement" and "Fleet Two Agreement") with Pioneer, ~~where~~pursuant to which we will provide hydraulic fracturing services with two committed fleets, subject to certain termination and release rights. The Fleet One Agreement ~~will be~~was effective as of January 1, 2023 and will terminate on August 31, 2023. The Fleet Two Agreement ~~will be~~was effective as of January 1, 2023 and ~~will terminate~~was terminated on ~~the one year anniversary of the date on which the fleet dedicated thereunder is able to provide the required services, which is currently expected to be on or before~~ May 1,12, 2023. ~~Pioneer may elect to extend the term of the Fleet Two Agreement for an additional one year term.~~

Revenue from services provided to Pioneer (including ~~idle fees and~~ Reservation fees) accounted for approximately ~~$100.2~~$45.4 million and ~~$147.3~~$115.2 million of our total revenue during the three months ended ~~September~~June 30, 2023 and 2022, ~~and 2021,~~ respectively. Revenue from services provided to Pioneer (including ~~idle fees and~~ Reservation fees) accounted for approximately ~~$338.9~~$99.7 million and ~~$364.3~~$238.7 million of our total revenue during the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, respectively.

As of ~~September~~June 30, ~~2022,~~2023, the total accounts receivable due from Pioneer, including estimated unbilled receivable for services we provided, amounted to approximately ~~$53.5~~$16.6 million and the amount due to Pioneer was $0. As of December 31, ~~2021,~~2022, the balance due from Pioneer for services we provided amounted to approximately ~~$62.1~~$46.2 million and the amount due to Pioneer was $0.

~~-15-~~-20-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 912 - Leases

Operating Leases

Description of Lease

In March 2013, we entered into a ~~ten year~~ten-year real estate lease contract (the "Real Estate One Lease") with a commencement date of April 1, 2013, as part of the expansion of our equipment yard. During the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, the Company made lease payments of approximately ~~$0.3~~$0.1 million and $~~0.3~~0.2 million, respectively. The assets and liabilities under this contract are ~~allocated between~~included in our ~~operating segments.~~Completion Services reportable segment. In addition to the contractual lease period, the contract ~~includes~~included an optional renewal of up to ten years, ~~and in management's judgment~~however, the ~~exercise of the renewal option is not reasonably assured. The contract does not include a residual value guarantee, covenants or financial restrictions. Further,~~Company terminated the Real Estate One Lease ~~does not contain variability in payments resulting from either an index change or rate change.~~at the end of the term, March 1, 2023.

We accounted for our Real Estate One Lease as an operating lease. This conclusion resulted from the existence of the right to control the use of the assets throughout the lease term. We did not account for the land separately from the building of the Real Estate One Lease because we concluded that the accounting effect was insignificant. ~~As of September 30, 2022, the weighted average discount rate and remaining lease term was approximately 6.7% and 0.5 years, respectively.~~

As part of our expansion of our hydraulic fracturing equipment maintenance program, we entered into a two year maintenance facility real estate lease contract (the "Maintenance Facility Lease") with a commencement date of March 14, 2022. During the ~~nine~~six months ended ~~September~~June 30, 2023 and 2022, the Company made lease payments of approximately $0.2 ~~million.~~million and $0.1 million, respectively. In addition to the contractual lease period, the contract includes an optional renewal for three additional periods of one year each, and in management's judgment the exercise of the renewal option is not reasonably assured. The contract does not include a residual value guarantee, covenants or financial restrictions. Further, the Maintenance Facility Lease does not contain variability in payments resulting from either an index change or rate change.

We accounted for our Maintenance Facility Lease as an operating lease. Our assumptions resulted from the existence of the right to control the use of the assets throughout the lease term. We did not account for the land separately from the building of the Maintenance Facility Lease because we concluded that the accounting effect was insignificant. As of ~~September~~June 30, ~~2022,~~2023, the weighted average discount rate and remaining lease term was approximately 3.4% and ~~1.4~~0.7 years, respectively.

In August 2022 and December 2022, we entered into a three year equipment ~~lease~~leases (the "Electric Fleet ~~Lease"~~Leases") for ~~two~~a total of four electric hydraulic fracturing fleets with 60,000 hydraulic horsepower ("HHP") per fleet. The ~~lease has~~Electric Fleet Leases contain an option to purchase the equipment after the initial three-year term for each lease. The Electric Fleet Leases have not yet commenced. We currently do not control the assets under the Electric Fleet ~~Lease~~Leases because they are currently being manufactured by the vendor and we have not taken possession of the assets. The ~~manufacturing and~~ delivery of the electric fleets is ~~estimated~~as each fleet is manufactured and we currently expect to take ~~up to ten months from~~delivery of most of the ~~lease execution date.~~electric fleets in the second half of 2023. Given that the Company has not yet taken possession of the assets under the Electric Fleet ~~Lease,~~Leases, the Company has not accounted for the right of use and lease obligation inon its balance sheet as of ~~September~~June 30, ~~2022.~~2023.

In October 2022, we entered into a real estate lease contract for 5.3 years (the "Real Estate Two Lease"), with a commencement date of March 1, 2023. During the six months ended June 30, 2023, the Company made lease payments of approximately $0.1 million. The assets and liabilities under this contract are included in our Completion Services reportable segment. In addition to the contractual lease period, the contract includes two optional renewals of one year each, and in management's judgment the exercise of the renewal option is not reasonably assured. The contract does not include a residual value guarantee, covenants or financial restrictions. Further, the Real Estate Two Lease does not contain variability in payments resulting from either an index change or rate change.

We accounted for our Real Estate Two Lease as an operating lease. Our assumptions resulted from the existence of the right to control the use of the assets throughout the lease term. We did not account for the land separately from the building of the Real Estate Two Lease because we concluded that the accounting effect was insignificant. As of June 30, 2023, the weighted average discount rate and remaining lease term was approximately 6.3% and 4.8 years, respectively.

As part of ~~September~~the Silvertip Acquisition, we assumed two real estate leases (the "Silvertip One Lease" and "Silvertip Two Lease," and collectively the "Silvertip Leases") with remaining terms of 4.8 years and 6.1 years, respectively, from the Silvertip Acquisition Date. During the six months ended June 30, ~~2022,~~2023, we extended the ~~total operating~~Silvertip One Lease for an additional 1.3 years. During the six months ended June 30, 2023, the Company made lease ~~right-of-use asset cost was approximately $1.9~~payments of approximately $0.1 million and ~~accumulated amortization was approximately $1.3 million. As of December 31, 2021, our total operating lease right-of-use asset cost was approximately $1.2~~$0.2 million on the Silvertip One Lease and ~~accumulat~~S~~ed amortization was approximately $0.8 million. For the nine months ended September 30, 2022~~ilvertip Two Lease, respectively. The assets and ~~2021, we~~liabilities under these contracts are recorded ~~operating lease cost of approximately $0.4 million and $0.3 million, respectively,~~ in our ~~statement of operations.~~wireline operating segment within our Completion Services reportable segment. The Silvertip Leases do not have any renewal options, residual value guarantees, covenants or financial restrictions. Further, the Silvertip Leases do not contain variability in payments resulting from either an index change or rate change.

~~-16-~~-21-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 912 - Leases (Continued)

We accounted for the Silvertip One Lease and the Silvertip Two Lease as operating leases. This conclusion resulted from the existence of the right to control the use of the assets throughout the lease term. We did not account for the land separately from the building of the Silvertip Leases because we concluded that the accounting effect was insignificant. As of June 30, 2023, the weighted average discount rate and remaining lease term for the Silvertip One Lease was approximately 6.3% and 5.4 years, respectively. As of June 30, 2023, the weighted average discount rate and remaining lease term for the Silvertip Two Lease was approximately 2.1% and 5.4 years, respectively.

In January 2023, we entered into a three year equipment lease (the "Power Equipment Lease") for certain power generation equipment. The Power Equipment Lease has not yet commenced. We currently do not control the assets under the lease and have not taken possession of the assets. Therefore, the Company has not accounted for the right of use and lease obligation in its balance sheet as of June 30, 2023.

In March 2023, we entered into a real estate lease contract for 5.7 years (the "Silvertip Three Lease"), with a commencement date of April 1, 2023. During the six months ended June 30, 2023, the Company made lease payments of approximately $0.03 million on the Silvertip Three Lease. The assets and liabilities under this contract are recorded in our wireline operating segment within our Completion Services reportable segment. The contract does not include a residual value guarantee, covenants or financial restrictions. Further, the Silvertip Three Lease does not contain variability in payments resulting from either an index change or rate change.

We accounted for the Silvertip Three Lease as an operating lease. This conclusion resulted from the existence of the right to control the use of the assets throughout the lease term. We did not account for the land separately from the building of the Silvertip Three Lease because we concluded that the accounting effect was insignificant. As of June 30, 2023, the weighted average discount rate and remaining lease term was approximately 6.3% and 5.4 years, respectively.

In June 2023, we entered into an office space lease contract for 5.0 years (the "Silvertip Office Lease"), with a commencement date of June 1, 2023. During the six months ended June 30, 2023, the Company made lease payments of approximately $0.01 million on the Silvertip Office Lease. The assets and liabilities under this contract are recorded in our wireline operating segment within our Completion Services reportable segment. The contract does not include a residual value guarantee, covenants or financial restrictions. Further, the Silvertip Office Lease does not contain variability in payments resulting from either an index change or rate change.

We accounted for the Silvertip Office Lease as an operating lease. This conclusion resulted from the existence of the right to control the use of the assets throughout the lease term. As of June 30, 2023, the weighted average discount rate and remaining lease term was approximately 6.5% and 4.9 years, respectively.

As of June 30, 2023, the total operating lease right-of-use asset cost was approximately $7.8 million, and accumulated amortization was approximately $2.1 million. As of December 31, 2022, our total operating lease right-of-use asset cost was approximately $4.6 million, and accumulated amortization was approximately $1.5 million. For the six months ended June 30, 2023 and 2022, we recorded operating lease cost of approximately $0.7 million and $0.3 million, respectively, in our statements of operations.

-22-

PROPETRO HOLDING CORP.

NOTESTOCONDENSEDCONSOLIDATEDFINANCIALSTATEMENTS

(Unaudited)

Note 12 - 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 ~~September~~June 30, ~~2022~~2023 are as follows:


($ in thousands)		Totals
2022		$	181
(in thousands)				(in thousands)	Totals
2023	2023	398		2023	$	737
2024	2024	50		2024	1,232
2025				2025	1,195
2026				2026	1,209
2027				2027	1,225
2028				2028	821
Total undiscounted future lease payments	Total undiscounted future lease payments	629		Total undiscounted future lease payments	6,419
Less: amount representing interest	Less: amount representing interest	(15)		Less: amount representing interest	(730)
Present value of future lease payments (lease obligation)	Present value of future lease payments (lease obligation)	$	614	Present value of future lease payments (lease obligation)	$	5,689

The total cash paid for amounts included in the measurement of our operating lease liability during the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 was approximately ~~$0.5~~$0.7 million. ~~The~~During the six months ended June 30, 2023, we recorded a non-cash lease obligation ~~we recorded upon~~totaling approximately $3.1 million as a result of our execution of the ~~Maintenance Facility~~Real Estate Two Lease, ~~was approximately $0.6 million~~.the Silvertip Three Lease and the Silvertip Office Lease and our extension of the Silvertip One Lease. During the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, total cash paid for amounts included in the measurement of our operating lease liability was approximately $0.3 million. During the six months ended June 30, 2022, we recorded a non-cash lease obligation of approximately $0.6 million as a result of our execution of the Maintenance Facility Lease.

Short-Term Leases

We elected the practical expedient, consistent with ASC 842, to exclude leases with an initial term of twelve months or less ("short-term lease") from our balance sheet and continue to record short-term leases as a period expense. For the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021~~2022 our short-term lease expense was approximately ~~$0.6~~$0.5 million and $0.4 million, respectively.

Note 1013 - Commitments and Contingencies

Commitments

We entered into certain commitments for fixed assets, consumables and services incidental to the ordinary conduct of our business, generally for quantities required for our operations and at competitive market prices. These commitments are designed to assure sources of supply and are not expected to be in excess of normal ~~requiremen~~requirements. ~~ts. At September 30, 2022, the total remaining lease commitments for all of our short-term leases and lodging commitments was approximately $1.9 million. In August 2022, we~~We entered into a contractual ~~arrangement~~ arrangements with our equipment ~~manufacturer~~manufacturers to purchase and convert ~~additional~~ Tier IV DGB equipment, with total cost of approximately ~~$43.0 million. The Company~~$16.4 million for the remainder of 2023. We also entered into the Electric Fleet Leases, ~~to lease electric hydraulic fracturing pumps with capacity of 60,000 HHP per fleet,~~ which ~~contains~~contain options to extend the ~~lease~~leases or purchase the equipment at the end of ~~the~~each lease. The lease payments are expected to commence when the Company takes possession of the electric hydraulic fracturing ~~pumps during~~fleets. We currently expect to take delivery of most of the electric hydraulic fracturing fleets in the second half of ~~2023.~~2023. The total estimated contractual commitment in connection with the Electric Fleet ~~Lease arrangement~~Leases is approximately ~~$49.3~~$96.4 million, which ~~includes~~excludes the cost associated with the option to purchase the equipment at the end of each lease. We also entered into the ~~lease.~~Power Equipment Lease. The total estimated contractual commitment in connection with the Power Equipment Lease is approximately $59.6 million.

The Company enters into purchase agreements with its sand suppliers (the "Sand Suppliers") to secure supply of sand as part of its normal course of business. The agreements with the Sand Suppliers require that the Company purchase a minimum volume of sand, based primarily on a certain percentage of our sand requirements from our customers or in certain situations based on predetermined fixed minimum volumes, otherwise certain penalties ~~("shortfall fees")~~(shortfall fees) may be charged. The shortfall fee represents liquidated damages and is either a fixed percentage of the purchase price for the minimum volumes or a fixed price per ton of unpurchased volumes. Our agreements with the Sand Suppliers expire at different times prior to December 31, 2025. Our sand agreement with one of our Sand Suppliers ~~has a one year take or pay commitment of $23.0 million~~ that will expire on ~~June 12, 2023.~~December 31, 2024 has a remaining take-or-pay commitment of $29.2 million. During the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, no shortfall fee was recorded. However, one of our Sand Suppliers previously filed a suit against us that includes claims related to alleged shortfall fees. On September 21, 2022, the Company agreed to a settlement of the claims in the suit with this Sand Supplier and paid the settlement amount on September 30, 2022. The suit was dismissed in connection with the settlement.

~~-17-~~-23-

PROPETRO HOLDING CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1013 - Commitments and Contingencies (Continued)

As of ~~September~~June 30, ~~2022,~~2023, the Company had issued letters of credit of ~~approximately $5.0~~approximately $6.0 million under the ~~revolving credit facility~~ABL Credit Facility in connection with the Company’s casualty insurance policy.

Contingent Liabilities

Legal Matters

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

~~In July 2020, a third~~ As amended ~~class action complaint was filed in~~by later complaints, the Logan Lawsuit by 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. Plaintiffs sued individually andasserted claims on behalf of a putative class of shareholders who purchased the Company’s common stock between March 17, 2017 and March 13, 2020 or purchased the Company's common stock pursuant to the Company's initial public offering in March 2017. Plaintiffs alleged violations of Sections 10(b) and 20(a) of the ~~Securities~~ Exchange Act ~~of 1934~~ and Rule l0b-5 promulgated thereunder, and Sections 11 and 15 of the Securities Act of 1933 against the Company, certain former officers and current and former directors, alleging that the defendants made allegedly inaccurate or misleading statements or omissions about the Company's business, operations and prospects. On ~~September 13, 2021, the Court partially granted and partially denied motions to dismiss filed by the Company and the individual defendants.~~

On August 11, 2022, the Company ~~agreed to~~entered into a ~~proposed~~ settlement of the ~~claims in the~~ Logan Lawsuit, pursuant to which ~~the court has preliminarily approved. Under the proposed settlement agreement,~~ the Company's insurers have paid a cash sum into a settlement fund to be distributed to members of the putative class.

In On May ~~2020,~~11, 2023, the U.S. District Court for the Western District of Texas consolidated two shareholder derivative lawsuits previously filed against the Company and certain of its current and former officers and directors into a single lawsuit captioned In re ProPetro Holding Corp. Derivative Litigation (the "Shareholder Derivative Lawsuit"). In August 2020, the plaintiffs in the Shareholder Derivative Lawsuit filed a consolidated complaint alleging (i) breaches of fiduciary duties, (ii) unjust enrichment and (iii) contribution. The plaintiffs did not quantify any alleged damages in their complaint but, in addition to attorneys’ fees and costs, they sought various forms of relief, including (i) damages sustained by the Company as a result of the alleged misconduct, (ii) punitive damages and (iii) equitable relief in the form of improvements to the Company’s governance and controls. On September 15, 2021, the Courtsettlement was granted ~~the Company's motion to dismiss the complaint in its entirety, without prejudice.~~

On November 19, 2021, the Company received a demand letter from a law firm representing one of the purported shareholders that previously filed the dismissed Shareholder Derivative Lawsuit. The demand letter alleged facts and claims substantially similar to the Shareholder Derivative Lawsuit. The Company's board of directors (the "Board") constituted a committee to evaluate the demand letter and recommend a course of action to the Board, and the committee retained counsel to assist with its review. ~~The committee concluded its investigation and recommended that the Board reject the demand letter. In October 2022, the Board accepted the committee's recommendation and rejected the demand letter.~~

The Company incurred legal settlements totaling $34.1 million during the three months ended September 30, 2022, consisting of the Logan Lawsuit and other settlements. The Logan Lawsuit settlement of $30.0 million was fully covered by insurance and was subsequently paid by the insurance company in October 2022. As of September 30, 2022 we recorded a receivable for the insurance recovery in connection with the Logan Lawsuit within other current assets and a liability due to plaintiffs in accrued and other current liabilities in our condensed consolidated balance sheet.

~~-18-~~

~~PROPETRO HOLDING CORP.~~

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

~~(Unaudited)~~

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

final court approval.

Environmental and Equipment Insurance

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

The Company is self-insured up to $10 million per occurrence for certain losses arising from or attributable to fire and/or explosion at the wellsites. No accrual was recorded in our financial statements in connection with this self-insurance ~~strategy.~~strategy because the occurrence of fire and/or explosion cannot be reasonably estimated.

Regulatory Audits

In 2020, the Texas Comptroller of Public Accounts (the "Comptroller") commenced a routine audit of the Company's motor vehicle and other related fuel taxes for the periods of July 2015 through December 2020. As of ~~September~~June 30, ~~2022,~~2023, the audit is still ongoing and the final outcome cannot be reasonably estimated.

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

In May 2022, the Company received a notification from the Comptroller that it will commence a routine audit of the Company's gross receipt taxes, which ~~will routinely cover~~typically covers up to a four-year period. As of ~~September~~June 30, ~~2022,~~2023, the audit is still ongoing and the final outcome cannot be reasonably estimated.

In June 2023, the Company received confirmation from the Comptroller that it will commence a routine audit of the Company's direct payment sales tax in August 2023 for the period February 1, 2020 to December 31, 2022. As of June 30, 2023, the audit is yet to commence, and as such, the final outcome cannot be reasonably estimated.

Note 1114 - Subsequent Event

~~On November 1, 2022,~~As part of our real estate consolidation strategy, on July 14, 2023 we entered into ~~a purchase~~an agreement to sell our corporate office building and ~~sale agreement with New Silvertip Holdco, LLC, to purchase 100% of equity interest of Silvertip~~the associated real property, which were included in our Completion Services ~~Operating, LLC (the "Silvertip Acquisition"). Under the terms~~segment. We expect to receive estimated cash proceeds of ~~the purchase agreement, we acquired,~~$5.0 million, subject to ~~exceptions~~customary closing requirements. We plan to lease office space in connection with the ~~Silvertip Acquisition, 100% of Silvertip Completion Services Operating, LLC equity interest for a consideration of both cash and shares~~relocation of our ~~Company. The total consideration paid consisted of 10.1 million shares of our Company, cash of $30.0 million, and certain other closing and transaction costs.~~corporate office.

~~-19-~~-24-

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.~~subsidiaries.

Overview

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

Our completion services segment includes hydraulic fracturing, wireline and cementing operations. Our hydraulic fracturing operations account for the significant portion of our operations, and our hydraulic fracturing operations revenue is approximately 79.0% of our total revenues, while wireline and cementing accounts for our remaining revenues. Our total available hydraulic horsepower ("HHP").

~~Our total available HHP~~ in our hydraulic fracturing operations as of ~~September~~June 30, ~~2022,~~ 2023, was ~~1,315,000~~1,270,000 HHP, which was comprised of ~~215,000~~390,000 HHP of our Tier IV Dynamic Gas Blending ("DGB") equipment and ~~1,100,000~~880,000 HHP of conventional Tier II equipment. Our ~~fleet could~~hydraulic fracturing fleets range from approximately 50,000 to 80,000 HHP depending on the job design and customer demand at the wellsite. Our equipment has been designed to handle the operating conditions commonly encountered in the Permian Basin and the region’s increasingly high-intensity well completions (including simultaneous hydraulic fracturing ("Simul-Frac"), which involves fracturing multiple wellbores at the same time), which are characterized by longer horizontal wellbores, more stages per lateral and increasing amounts of proppant per well. With the industry transition to lower emissions equipment and ~~simultaneous hydraulic fracturing ("Simul-Frac")~~,Simul-Frac, in addition to several other changes to our customers' job designs, we believe that our available capacity could decline if we decide to reconfigure our fleets to increase active HHP and backup HHP at ~~the~~ wellsites. In addition, in ~~September~~ 2021 and ~~August~~ 2022, we committed to additional conversions of our Tier II equipment to Tier IV DGB, and purchase of new Tier IV DGB equipment. As such, we entered into a conversion and purchase arrangements with our equipment manufacturers for a total ~~of 187,500~~452,500 HHP of Tier IV DGB equipment and as of ~~September~~June 30, ~~2022,~~2023, we have received ~~125,000~~390,000 HHP of the converted and new Tier IV DGB equipment and expect to receive the remaining 62,500 HHP ~~at different times through~~by the ~~second half~~end of ~~2022.~~2023. In ~~August~~ 2022, we entered into three-year electric fleet leases for a ~~three year Electric Fleet Lease for two~~total of four electric hydraulic fracturing fleets with 60,000 HHP per fleet. ~~This lease has not yet commenced.~~

~~In 2019, we entered into a purchase commitment for~~ ~~DuraStim~~®We currently expect to take delivery of most of the electric ~~powered~~ hydraulic fracturing ~~equipment. During~~fleets in the second ~~quarter 2022, we determined that certain~~half of 2023. We currently have ~~DuraStim®~~ 23~~equipment was impaired~~ wireline units and ~~recorded approximately $57.5 million of impairment expense in our pressure pumping reportable segment.~~28 cement units.

On March 31, 2022, we entered into an amended and restated pressure pumping services agreement (the "A&R Pressure Pumping Services Agreement")~~, which~~ to replace the Pioneer Services Agreement that was ~~initially~~ entered into in connection with the Pioneer Pressure Pumping Acquisition. The A&R Pressure Pumping Services Agreement, which was effective from January 1, 2022 ~~and continues through~~to December 31, ~~2022. The A&R Pressure Pumping Services Agreement~~2022, reduced the number of contracted fleets from eight fleets to six ~~fleets from eight~~ fleets, modified the pressure pumping scope of work and pricing mechanism for contracted fleets, and replaced the idle fees arrangement with equipment reservation fees (the "Reservation fees"). As part of the Reservation fees arrangement, the Company ~~will be~~was entitled to receive compensation for all eligible contracted fleets that ~~are~~were made available to Pioneer at the beginning of every quarter in 2022 through the term of the A&R Pressure Pumping Services Agreement. This agreement expired at the conclusion of its term and was replaced by the Fleet One Agreement and Fleet Two Agreement described below.

On October 31, 2022, we entered into two pressure pumping services agreements (the "Fleet One Agreement" and "Fleet Two Agreement") with Pioneer, pursuant to which we will provide hydraulic fracturing services with two committed fleets, subject to certain termination and release rights. The Fleet One Agreement was effective as of January 1, 2023 and will terminate on August 31, 2023. The Fleet Two Agreement was effective as of January 1, 2023 and was terminated on May 12, 2023.

Effective September 1, 2022, we disposed of our coiled tubing assets to STEP Energy Services Ltd. ("STEP") and shut down our coiled tubing operations. We received cash of approximately $2.8 million and 2.6 million common shares of STEP valued at $11.9 million as consideration. Upon the sale of our coiled tubing assets, we recorded a loss on sale of $13.8 million.

-25-

On November 1, 2022, we consummated the acquisition of all of the outstanding limited liability company interests of Silvertip Completion Services Operating, LLC ("Silvertip"), which provides wireline perforation and ancillary services solely in the Permian Basin in exchange for 10.1 million shares of our common stock valued at $106.7 million, $30.0 million of cash, the payoff of $7.2 million of assumed debt, and the payment of certain other closing and transaction costs. At June 30, 2023, we had 23 wireline units available to provide wireline perforation and ancillary services. The Silvertip Acquisition positions the Company as a more integrated and diversified completions-focused oilfield services provider headquartered in the Permian Basin.

Our competitors include many large and small oilfield services companies, including Halliburton Company, Liberty Energy Inc., ProFrac Holding Corp., Nextier Oilfield Solutions Inc., Patterson-UTI Energy Inc., RPC, Inc., and a number of private and locally-oriented businesses. The markets in which we operate are highly competitive. To be successful, an oilfield services company must provide services that meet the specific needs of oil and natural gas E&P companies at competitive prices. Competitive factors impacting sales of our services are price, reputation, technical expertise, emissions profile, service and equipment design and quality, and health and safety standards. Although we believe our customers consider all of these factors, we believe price is a key factor in an E&P company's criteria in choosing a service provider. However, we have recently observed the energy industry and our customers shift to lower emissions equipment, which we believe will be an increasingly important factor in an E&P company's selection of a service provider. The transition to lower emissions equipment has been challenging for companies in the oilfield service industry because of the ~~significant~~ capital ~~investment required for next generation equipment and the current pricing environment with the service industry, which remains in recovery phase.~~requirements. While we seek to price our services competitively, we believe many of our customers elect to work with us based on our operational efficiencies, productivity, equipment portfolio and quality, reliability, ability to manage multifaceted logistics challenges, commitment to safety and the ability of our people to handle the most complex Permian Basin well completions.

Our substantial market presence in the Permian Basin positions us well to capitalize on drilling and completion activity in the region. Primarily, our operational focus has been in the Permian Basin's Midland sub-basin, where our customers have

~~-20-~~

operated. However, we have ~~recently~~ increased our operations in the Delaware sub-basin and are well-positioned to support further increases to our activity in this area in response to demand from our customers. Over time, we expect the Permian Basin's Midland and Delaware sub-basins to continue to command a disproportionate share of future North American E&P spending.

Through our ~~pressure pumping~~Completion Services segment, ~~(which also~~which includes our hydraulic fracturing, cementing ~~operations),~~and wireline operations, we primarily provide hydraulic fracturing services to E&P companies in the Permian Basin. ~~Our~~During the three months ended June 30, 2023, our hydraulic fracturing, ~~fleet~~cementing and wireline operations accounted for 79.0%, 6.3% and 14.7% of our total revenue, respectively. During the six months ended June 30, 2023, our hydraulic fracturing, cementing and wireline operations accounted for 79.0%, 6.3% and 14.7% of our total revenue, respectively. Our equipment has been designed to handle ~~the~~Permian Basin specific operating conditions ~~commonly experienced in the Permian Basin~~ and the region's increasingly high-intensity well completions, ~~(including Simul-Frac, which involves fracturing multiple wellbores at the same time),~~ which are characterized by longer horizontal wellbores, more frac stages per lateral and increasing amounts of proppant per well. We plan to continually reinvest in our equipment to ensure optimal performance and reliability.

~~Effective September 1, 2022, we disposed~~Our hydraulic fracturing, wireline and cementing operations have been aggregated into one reportable segment: "Completion Services." In connection with our divestiture of our coiled tubing ~~assets~~operations and the Silvertip Acquisition, we have revised our reportable segment presentation from Pressure Pumping to ~~a subsidiary of STEP~~Completion Services and ~~shut down our~~have restated prior periods accordingly. Our now discontinued coiled tubing, ~~operations. We received cash of approximately $2.8 million~~drilling and ~~2,616,460 common shares of STEP valued at $11.9 million as consideration. Upon~~flowback operations were aggregated into the ~~sale of our coiled tubing assets, we recorded a loss on sale of $13.8 million~~."All Other" category.

Commodity Price and Other Economic Conditions

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

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

The global public health crisis associated with the COVID-19 pandemic also has had an adverse effect on global economic activity and the oil and gas industry. Some of the challenges resulting from the COVID-19 pandemic that have impacted our business include restrictions on movement of personnel and associated gatherings, shortage of skilled labor, cost inflation and supply chain disruptions. In light of the COVID-19 pandemic, most companies, including our customers in the Permian Basin, reacted by closely managing their operating budget and exercising capital discipline. In addition, OPEC+ has indicated that they will continue with their plans to manage production levels, including a recent announcement to reduce production levels by 2 million barrels per day.

~~The Russia-Ukraine war,~~ and the adverse impacts of the COVID-19 pandemic in recent years ~~including inflation,~~ have resulted in volatility in supply and demand dynamics for crude ~~oil~~oil and associated volatility in crude oil pricing. As the global response to the COVID-19 pandemic began to wane, the demand and prices for crude oil increased from the lows experienced in 2020, with ~~In 2022, global~~the WTI average crude oil ~~prices have exceeded~~price reaching approximately ~~$98~~$94 per barrel ~~which is~~in 2022, the highest ~~prices have been~~average price in the ~~last ten~~prior nine years. However, in 2023, the WTI average crude oil price declined to approximately $70 per barrel in June 2023 and $75 per barrel for the six months ended in June 30, 2023. We believe that the ~~recent surge in global~~volatility of crude oil prices isin recent years has been partly driven by declines in crude oil supplies, concerns over sanctions resulting from Russia's invasion of Ukraine, slower crude oil production growth due to the lack of

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reinvestment in the oil and gas industry in the last two years, recent OPEC+ production cuts of approximately 1.16 million barrels per day and ~~increased demand for oil~~concerns of a potential global recession resulting from rising inflation and ~~gas products, coupled with adverse impact of the Russia-Ukraine war, which has led to various sanctions in Russian crude oil supply and businesses.~~ interest rates.

With the significant increase in global crude oil prices from 2021, including the WTI crude oil ~~prices,~~price, there has been an increase in the Permian Basin rig count from approximately 179 at the beginning of 2021 to approximately ~~344~~341 at the end of ~~September 2022,~~June 2023, according to Baker Hughes. Following the increase in rig count and the WTI crude oil price, the oilfield service industry has experienced increased demand for its ~~pressure pumping~~completion services, and improved pricing. AsHowever, we have recently experienced a ~~result of~~3% decrease in the ~~growing~~rig count between January and June 2023 which resulted in a reduction in the demand for ~~pressure pumping~~completion services and ~~significant cost inflation across the industry, we negotiated~~pressure on pricing ~~increases with certain~~ of our ~~customers~~services.

Sustained levels of high inflation have likewise caused the U.S. Federal Reserve and other central banks to increase interest rates, and to the extent elevated inflation remains, we may experience further cost increases for our ~~pressure pumping services, depending on job design. Although we are currently operating~~operations, including interest rates, labor costs and equipment. We cannot predict any future trends in ~~an improved pricing environment,~~ the ~~rapid~~rate of inflation and crude oil prices. A significant increase in ~~cost~~or continued high levels of inflation, ~~and supply chain tightness could adversely impact our future profitability, if~~to the extent we are unable to timely pass-through the cost increases to our ~~customers.~~customers, or further declines in crude oil prices would negatively impact our business, financial condition and results of operations.

Government regulations and investors are ~~demanding~~encouraging the oil and gas industry, including the upstream and oilfield service companies, to transition to a lower emissions operating ~~environment, including the upstream and oilfield service companies.~~environment. As a result, we are working with our customers and equipment manufacturers to transition our equipment 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

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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. IfWe have transitioned our hydraulic fracturing equipment portfolio from approximately 10% lower emissions equipment in 2021 to approximately 35% in 2022, and expect to increase to approximately 65% by year end 2023. To the extent any of our customers have certain expectations or requirements with respect to emissions reductions from their contractors, if we are unable to continue quickly ~~transition~~transitioning to lower emissions equipment, ~~and meet our and our customers’ emissions goals,~~ the demand for our services could be adversely impacted.

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

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

How We Evaluate Our Operations

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

Adjusted EBITDA and Adjusted EBITDA Margin

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

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

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net income/(loss), operating income/(loss), cash flow from operating activities or any other measure of financial performance presented in accordance with GAAP.

Note Regarding Non-GAAP Financial Measures

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

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


	Three Months Ended June 30, 2023
	Completion Services		All Other		Total
Net income	$	39,257	$	—	$	39,257
Depreciation and amortization	52,889		—		52,889
Interest expense	1,180		—		1,180
Income tax expense	12,118		—		12,118
Loss on disposal of assets	3,065		—		3,065
Stock-based compensation	3,758		—		3,758
Other income (1)	(72)		—		(72)
Other general and administrative expense, (net) (2)	263		—		263
Retention bonus and severance expense	355		—		355
Adjusted EBITDA	$	112,813	$	—	$	112,813

	Three Months Ended June 30, 2022
	Completion Services		All Other		Total
Net loss	$	(32,119)	$	(741)	$	(32,860)
Depreciation and amortization	40,131		838		40,969
Impairment expense	57,454		—		57,454
Interest expense	669		—		669
Income tax benefit	(8,069)		—		(8,069)
Loss on disposal of assets	12,970		8		12,978
Stock-based compensation	3,458		—		3,458
Other income	(6)		—		(6)
Other general and administrative expense, (net) (2)	1,345		—		1,345
Severance expense	9		—		9
Adjusted EBITDA	$	75,842	$	105	$	75,947

~~-23-~~-28-


		Nine Months Ended September 30, 2022							Six Months Ended June 30, 2023
		Pressure Pumping		All Other		Total			Completion Services		All Other		Total
Net income (loss)		$	51,782	$	(62,794)	$	(11,012)
Net income								Net income	$	67,990	$	—	$	67,990
Depreciation and amortization	Depreciation and amortization	91,194		2,540		93,734		Depreciation and amortization	103,687		—		103,687
Impairment expense		57,454		—		57,454
Interest expense	Interest expense	—		1,040		1,040		Interest expense	1,847		—		1,847
Income tax benefit		—		(1,164)		(1,164)
Loss (gain) on disposal of assets		61,952		13,288		75,240
Income tax expense								Income tax expense	20,474		—		20,474
Loss on disposal of assets								Loss on disposal of assets	25,145		—		25,145
Stock-based compensation	Stock-based compensation	—		18,128		18,128		Stock-based compensation	7,294		—		7,294
Other income (2) (3)		(2,668)		(7,081)		(9,749)
Other general and administrative expense (1)		5,060		2,651		7,711
Other expense (1)								Other expense (1)	3,632		—		3,632
Other general and administrative expense, (net) (2)								Other general and administrative expense, (net) (2)	1,209		—		1,209
Severance expense	Severance expense	1,061		37		1,098		Severance expense	700		—		700
Adjusted EBITDA	Adjusted EBITDA	$	265,835	$	(33,355)	$	232,480	Adjusted EBITDA	$	231,978	$	—	$	231,978

		Nine Months Ended September 30, 2021							Six Months Ended June 30, 2022
		Pressure Pumping		All Other		Total			Completion Services		All Other		Total
Net income (loss)		$	(5,426)	$	(28,527)	$	(33,953)
Net loss								Net loss	$	(20,036)	$	(1,007)	$	(21,043)
Depreciation and amortization	Depreciation and amortization	97,307		2,946		100,253		Depreciation and amortization	77,293		1,680		78,973
Impairment expense								Impairment expense	57,454		—		57,454
Interest expense	Interest expense	—		477		477		Interest expense	803		—		803
Income tax benefit	Income tax benefit	—		(11,639)		(11,639)		Income tax benefit	(3,932)		—		(3,932)
Loss (gain) on disposal of assets	Loss (gain) on disposal of assets	40,792		(292)		40,500		Loss (gain) on disposal of assets	22,954		(7)		22,947
Stock-based compensation	Stock-based compensation	—		8,405		8,405		Stock-based compensation	14,822		—		14,822
Other income(3)	Other income(3)	—		(1,178)		(1,178)		Other income(3)	(10,364)		—		(10,364)
Other general and administrative expense, (net) ~~(1)~~(2)	Other general and administrative expense, (net) ~~(1)~~(2)	—		(5,670)		(5,670)		Other general and administrative expense, (net) ~~(1)~~(2)	2,791		—		2,791
Severance expense	Severance expense	—		612		612		Severance expense	$	29	$	—	$	29
Adjusted EBITDA	Adjusted EBITDA	$	132,673	$	(34,866)	$	97,807	Adjusted EBITDA	$	141,814	$	666	$	142,480

(1)Includes unrealized loss on short-term investment of $0.1 million and $3.9 million for the three and six months ended June 30, 2023, respectively.

~~(1)~~(2)Other general and administrative expense, (net of reimbursement from insurance carriers) primarily relates to nonrecurring professional fees paid to external consultants in connection with our audit committee review, SEC investigation, shareholder litigation, legal settlement to a vendor and other legal matters, net of insurance recoveries. During the three and ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023, we received reimbursement of ~~approximately $3.4~~approximately $0 and $0.3 million, ~~and $6.9 million~~, respectively, from our insurance carriers in connection with the SEC investigation and shareholder litigation. During the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, we received reimbursement of approximately ~~$1.4~~$2.4 million and ~~$8.1~~$3.5 million, ~~respectively.~~respectively, from our insurance carriers in connection with the SEC investigation and shareholder litigation. See "Note 13 - Commitments and Contingencies—Contingent Liabilities—Legal Matters" for further information.

~~(2)~~(3)Includes $10.7 million of net tax refund (net of advisory fees) received in March 2022 from the Texas Comptroller of Public Accounts in connection with limited sales, excise and use tax ~~beginning~~of the period July 1, 2015 through December 31, 2018.

~~(3)~~Includes $2.7 million non cash income from fixed asset inventory received as part of a settlement of warranty claims with an equipment manufacturer and a $3.3 million unrealized loss on short-term investment.

~~-24-~~-29-

Results of Operations

WeIn 2023, we conducted our business through three operating segments: hydraulic fracturing, cementing and ~~coiled tubing.~~wireline. For reporting purposes, the hydraulic fracturing, cementing and ~~cementing~~wireline operating segments are aggregated into ~~our~~ one reportable segment—~~pressure pumping. However, we~~Completion Services. We disposed of our coiled tubing assets and shut down our coiled tubing ~~operating segment~~operations effective September 1, 2022. The results of our coiled tubing operations prior to September 1, 2022 are reflected in the "All Other" category.

On November 1, 2022, we consummated the acquisition of all of the outstanding limited liability company interests of Silvertip, which provides wireline perforation and ancillary services (wireline operating ~~segment and corporate administrative expenses (inclusive~~segment) solely in the Permian Basin in exchange for 10.1 million shares of our ~~total income tax expense (benefit),~~common stock valued at $106.7 million, $30.0 million of cash, the payoff of $7.2 million of assumed debt, and the payment of certain other ~~(income)~~closing and ~~expense~~transaction costs. At June 30, 2023, we had 23 wireline units available to provide wireline perforation and ~~interest expense) are~~ancillary services. The Silvertip Acquisition positions the Company as a more integrated and diversified completions-focused oilfield services provider headquartered in the Permian Basin. The Company's 2023 results include the impact of Silvertip's operations for the entire period which was not included in our 2022 results herein because we acquired Silvertip in November 2022. Accordingly, the ~~"all other" category. Total corporate administrative expense for~~full impact of the ~~three and nine months ended September 30, 2022 was $20.4 million and $45.4 million,~~ ~~respectively. Total corporate administrative expense for~~results of Silvertip may affect the ~~three and nine months ended~~ ~~September 30, 2021~~ wa~~s $13.5 million and $25.1 million,~~ ~~respectively.~~

~~Our hydraulic fracturing operating segment revenue approximated 91.7% and 92.7%~~comparability of our ~~pressure pumping~~2023 results when compared to prior period. See "Note 7 —Reportable Segment Information"in the notes to our financial statements included in this Form 10-Qfor our revenue ~~during the three~~contribution for wireline operations and ~~nine~~ ~~months ended September 30, 2022, respectively. During the three and nine~~ ~~months~~ ~~ended~~ ~~September 30, 2021, our hydraulic fracturing~~other operating ~~segment revenue approximated 93.4% and 93.5% of our pressure pumping revenue,~~ ~~respectively.~~segments.

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


(in thousands, except for percentages)	(in thousands, except for percentages)	Three Months Ended September 30,						Change Increase (Decrease)					(in thousands, except for percentages)	Three Months Ended June 30,						Change Increase (Decrease)
		2022			2021			$			%			2023			2022			$			%
Revenue	Revenue	$	333,014		$	250,099		$	82,915		33.2	%	Revenue	$	435,249		$	315,083		$	120,166		38.1	%
Less (Add):	Less (Add):												Less (Add):
Cost of services (1)	Cost of services (1)	224,118			188,690			35,428			18.8	%	Cost of services (1)	297,791			218,813			78,978			36.1	%
General and administrative expense (2)	General and administrative expense (2)	28,190			21,348			6,842			32.0	%	General and administrative expense (2)	29,021			25,135			3,886			15.5	%
Depreciation and amortization	Depreciation and amortization	30,417			33,531			(3,114)			(9.3)	%	Depreciation and amortization	52,889			40,969			11,920			29.1	%

Impairment expense													Impairment expense	—			57,454			(57,454)			(100.0)	%
Loss on disposal of assets	Loss on disposal of assets	36,636			12,424			24,212			194.9	%	Loss on disposal of assets	3,065			12,978			(9,913)			(76.4)	%
Interest expense	Interest expense	237			143			94			65.7	%	Interest expense	1,180			669			511			76.4	%
Other expense		616			309			307			99.4	%
Other income													Other income	(72)			(6)			66			1,100.0	%
Income tax expense (benefit)	Income tax expense (benefit)	2,768			(1,279)			4,047			316.4	%	Income tax expense (benefit)	12,118			(8,069)			20,187			250.2	%
Net income (loss)	Net income (loss)	$	10,032		$	(5,067)		$	15,099		298.0	%	Net income (loss)	$	39,257		$	(32,860)		$	72,117		219.5	%

Adjusted EBITDA (3)	Adjusted EBITDA (3)	$	90,000		$	42,098		$	47,902		113.8	%	Adjusted EBITDA (3)	$	112,813		$	75,947		$	36,866		48.5	%
Adjusted EBITDA Margin (3)	Adjusted EBITDA Margin (3)	27.0		%	16.8		%	10.2		%	60.7	%	Adjusted EBITDA Margin (3)	25.9		%	24.1		%	1.8		%	7.5	%

Pressure pumping segment results of operations:
Completion Services segment results of operations:													Completion Services segment results of operations:
Revenue	Revenue	$	330,780		$	245,641		$	85,139		34.7	%	Revenue	$	435,249		$	309,445		$	125,804		40.7	%
Cost of services	Cost of services	$	220,299		$	184,972		$	35,327		19.1	%	Cost of services	$	297,791		$	213,622		$	84,169		39.4	%
Adjusted EBITDA (3)	Adjusted EBITDA (3)	$	102,550		$	53,975		$	48,575		90.0	%	Adjusted EBITDA (3)	$	112,813		$	75,842		$	36,971		48.7	%
Adjusted EBITDA Margin (4)	Adjusted EBITDA Margin (4)	31.0		%	22.0		%	9.0		%	40.9	%	Adjusted EBITDA Margin (4)	25.9		%	24.5		%	1.4		%	5.7	%

(1)Exclusive of depreciation and amortization.

(2)Inclusive of stock-based compensation.

(3)For definitions of the non-GAAP financial measures of Adjusted EBITDA and Adjusted EBITDA margin and reconciliation of Adjusted EBITDA to our most directly comparable financial measures calculated in accordance with GAAP, please read "How We Evaluate Our Operations". Included in our Adjusted EBITDA is reservation ~~and idle~~ fees of $~~6.8 million~~0 and $06.8 million for the three months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, respectively.

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

~~-25-~~-30-

Three Months Ended ~~September~~June 30, ~~2022~~2023 Compared to the Three Months Ended ~~September~~June 30, ~~2021~~2022

Revenues. Revenues increased ~~33.2%~~38.1%, or ~~$82.9~~$120.2 million, to ~~$333.0~~$435.2 million during the three months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$250.1~~$315.1 million during the three months ended ~~September~~June 30, ~~2021.~~2022. Our ~~pressure pumping~~Completion Services segment revenues increased ~~34.7%~~40.7%, or ~~$85.1~~$125.8 million, for the three months ended ~~September~~June 30, ~~2022,~~2023, as compared to the three months ended ~~September~~June 30, ~~2021.~~2022. The increases were primarily attributable to the significant increase in our existing and new customers' activity levels, resulting in higher demand for ~~pressure pumping~~completion services and consumables (sand and chemical), improved ~~pricing.~~pricing and the addition of wireline operations. The addition of wireline operations contributed $63.8 million of the increase in total revenues. As a result of our customers' increased activity levels, our effectively utilized hydraulic fracturing fleet count rose to approximately ~~14.8~~16 active fleets during the three months ended ~~September~~June 30, ~~2022,~~2023, from approximately ~~13.8~~15 active fleets for the three months ended ~~September~~June 30, ~~2021. Included~~2022. The effective utilized fleet count is determined by dividing the total number of days a fleet was actively working at the wellsite during the month by a total of 25 days (predetermined number of expected active work days in ~~our~~the month). Our revenue for the three months ended ~~September~~June 30, 2023 and 2022, ~~and 2021 was revenue generated from~~included reservation ~~and idle~~ fees charged to ~~our~~a customer of approximately $0 and $6.8 million, ~~and $0,~~ respectively.

Revenues from services other than ~~pressure pumping~~Completion Services decreased ~~49.9%~~100.0%, or ~~$2.2~~$5.6 million, to ~~$2.2~~$0 for the three months ended June 30, 2023, as compared to $5.6 million for the three months ended ~~September~~June 30, ~~2022, as compared to $4.5 million for the three months ended September 30, 2021.~~2022. The decrease in revenue from services other than ~~pressure pumping~~Completion Services was ~~primarily attributable~~due to the ~~closure~~discontinuation of our coiled tubing operations effective September 1, 2022.

Cost of Services. Cost of services increased ~~18.8%~~36.1%, or ~~$35.4~~$79.0 million, to ~~$224.1~~$297.8 million for the three months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$188.7~~$218.8 million during the three months ended ~~September~~June 30, ~~2021.~~2022. Cost of services in our ~~pressure pumping~~Completion Services segment increased ~~$35.3~~$84.2 million for the three months ended ~~September~~June 30, ~~2022,~~2023, as compared to the three months ended ~~September~~June 30, ~~2021.~~2022. These increases were primarily attributable to the significantly increased activity levels resulting from the increased demand for our services as compared to 2022, increase in consumables, the addition of wireline operations and the impact of general cost inflation. The addition of wireline operations contributed to $42.1 million of the increase in total cost of services. As a percentage of ~~pressure pumping~~Completion Services segment revenues (including reservation ~~and idle~~ fees), ~~pressure pumping~~Completion Services cost of services was ~~66.6%~~68.4% for the three months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~75.3%~~69.0% for the three months ended ~~September~~June 30, ~~2021.~~2022. Excluding reservation ~~and idle~~ fees revenue of $0 and $6.8 million ~~and $0~~ recorded during the three months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, respectively, our ~~pressure pumping~~Completion Services cost of services as a percentage of ~~pressure pumping~~Completion Services revenues decreased to ~~68.0%~~68.4% during the three months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~75.3%~~70.6% for the three months ended ~~September~~June 30, ~~2021.~~2022. The decrease in the percentages was primarily a result of increased operational efficiencies and activity levels and improved customer pricing, ~~across our customer base.~~partially offset by costs of $11.2 million associated with the replacement of fluid ends during the three months ended June 30, 2023. Fluid ends were capitalized and depreciated in 2022. Effective January 1, 2023, the Company commenced expensing fluid ends as part of cost of services rather than capitalizing fluid ends as part of property and equipment as a result of the change in estimated useful life.

General and Administrative Expenses. General and administrative expenses increased ~~32.0%~~15.5%, or ~~$6.8~~$3.9 million, to ~~$28.2~~$29.0 million for the three months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$21.3~~$25.1 million for the three months ended ~~September~~June 30, ~~2021.~~2022. The net increase was primarily attributable to an(i) a $1.7 million increase ~~during 2022~~ in ~~(i) non-recurring legal~~payroll and related expenses, (ii) a $1.2 million increase in consulting fees, and ~~settlement~~(iii) a $2.1 million increase in other general and administrative expenses, ~~incurred in connection with a settlement with a vendor, of approximately $5.3 million, (ii) consulting~~ and professional fees of approximately $2.2 million, (iii) non-recurring severance expense incurred in connection with the terms of the separation agreement of a former employee of approximately $1.1 million and (iv) property taxes of approximately $0.8 million, which was partially offset by ~~(v)~~ a $1.1 million decrease in ~~payroll~~legal settlements.

Excluding nonrecurring and non-cash items (stock-based compensation, insurance reimbursements, legal settlements, nonrecurring transaction expenses, ~~of $2.5~~retention bonuses and severance expenses), general and administrative expenses were $24.6 million ~~and (vi) a net decrease of approximately $0.1~~during the three months ended June 30, 2023, as compared to $20.3 million ~~in other general administrative expenses.~~during the three months ended June 30, 2022.

Depreciation and Amortization. Depreciation and amortization ~~decreased 9.3%~~increased 29.1%, or ~~$3.1~~$11.9 million, to ~~$30.4~~$52.9 million for the three months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$33.5~~$41.0 million for the three months ended ~~September~~June 30, ~~2021.~~2022. The ~~decrease~~increase was primarily attributable to (i) assets placed into service since June 30, 2022, (ii) shortening of useful lives of power ends and hydraulic fracturing units effective January 1, 2023 and (iii) the ~~decrease in our fixed asset base, partly attributable to the disposal~~addition of ~~certain fixed~~wireline assets which included $3.2 million of depreciation and $1.4 million of amortization of intangible assets.

Impairment Expense. There was no impairment expense during the ~~period.~~three months ended June 30, 2023. During the three months ended June 30, 2022, we recorded a loss of $57.5 million in connection with the impairment of our DuraStim® electric powered hydraulic fracturing equipment.

-31-

Loss on Disposal of Assets. Loss on the disposal of assets ~~increased 194.9%~~decreased 76.4%, or ~~$24.2~~$9.9 million, to ~~$36.6~~$3.1 million for the three months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$12.4~~$13.0 million for the three months ended ~~September~~June 30, ~~2021.~~2022. The decrease was primarily attributable to the Company expensing costs associated with replacement of fluid ends as part of cost of services resulting from the change in estimated useful life effective January 1, 2023.

Interest Expense. Interest expense increased to $1.2 million for the three months ended June 30, 2023, as compared to $0.7 million for the three months ended June 30, 2022. The increase was primarily attributable to ~~the divestiture of~~outstanding borrowings under our coiled tubing operations and the significant increase in our utilization levels, resulting in an increase in the operational intensity on our pressure pumping equipment. Upon sale or retirement of property and equipment, including replaced fluid and power ends, the cost and related accumulated depreciation of such assets or components are removed from the balance sheet and the net amount is recognized as loss on disposal of assets.

~~Interest Expense.~~ There was no significant change in interest expense. Interest expense slightly increased to approximately $0.2 million for the three months ended September 30, 2022, as compared to $0.1 million for the three months ended September 30, 2021.

~~Other Expense (Income).~~ There was no significant change in other expense (income). Other expense was approximately $0.6 million for the three months ended September 30, 2022, as compared to other expense of $0.3 million for the three months ended September 30, 2021. However, included in our other expense (income)ABL Credit Facility during the three months ended ~~September~~June 30, 2022 are $2.7 million of non-cash income from equipment parts inventory received from our equipment manufacturer as settlement of our warranty claims, partially offset by a $3.3 million unrealized loss on short-term investment and other expense relating2023, compared to ~~our lender's commitment fees.~~no outstanding borrowings during the three months ended June 30, 2022.

~~-26-~~

Income Taxes. ~~For the three months ended September 30, 2022, the Company has utilized the discrete effective tax rate method as allowed by Accounting Standards Codification (“ASC”) 740-270-30-18,~~ ~~Income Taxes - Interim Reporting~~ ~~to calculate its interim tax provision. The discrete method treats the year-to-date period as if it was the annual period and determines the~~Total income tax expense ~~or benefit on that basis. The Company believes that, at this time, the use of this discrete method is more appropriate than the annual effective tax rate method~~ was the annual effective tax rate is not reliable because small changes in estimated “ordinary” income would result in significant changes in the estimated annual effective tax rate. Total income tax benefit was $2.8$12.1 million resulting in an effective tax rate of ~~21.6% for~~23.6% for the three months ended ~~September~~June 30, ~~2022,~~2023, as compared to income tax benefit of ~~$1.3~~$8.1 million or an effective tax rate of ~~20.1%~~19.7% for the three months ended ~~September~~June 30, ~~2021.~~2022. The change in income tax ~~benefit~~expense (benefit) recorded during the three months ended ~~September~~June 30, ~~2022,~~2023, compared to the three months ended ~~September~~June 30, ~~2021,~~2022, is primarily attributable to the difference in the estimated pre-tax ~~loss in 2022,~~income (loss) for 2023, as compared to ~~2021.~~2022.

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

(in thousands, except for percentages)
Nine Months Ended September 30, Change
Increase (Decrease)
2022 2021 $ %
Revenue $ 930,776 $ 628,444 $ 302,332 48.1 %
Less (Add):
Cost of services (1)
640,202 474,905 165,297 34.8 %
General and administrative expense (2)
85,031 59,079 25,952 43.9 %
Depreciation and amortization 93,734 100,253 (6,519) (6.5) %
Impairment expense 57,454 — 57,454 100.0 %
Loss on disposal of assets 75,240 40,500 34,740 85.8 %
Interest expense 1,040 477 563 118.0 %
Other income (9,749) (1,178) 8,571 727.6 %
Income tax benefit (1,164) (11,639) (10,475) (90.0) %
Net loss $ (11,012) $ (33,953) $ (22,941) (67.6) %
Adjusted EBITDA (3)
$ 232,480 $ 97,807 $ 134,673 137.7 %
Adjusted EBITDA Margin (3)
25.0 % 15.6 % 9.4 % 60.3 %
Pressure pumping segment results of operations:
Revenue $ 917,336 $ 617,293 $ 300,043 48.6 %
Cost of services $ 626,554 $ 464,230 $ 162,324 35.0 %
Adjusted EBITDA (3)
$ 265,835 $ 132,673 $ 133,162 100.4 %
Adjusted EBITDA Margin (4)
29.0 % 21.5 % 7.5 % 34.9 %


(in thousands, except for percentages)	Six Months Ended June 30,						Change Increase (Decrease)
	2023			2022			$			%
Revenue	$	858,819		$	597,763		$	261,056		43.7	%
Less (Add):
Cost of services (1)	578,277			416,083			162,194			39.0	%
General and administrative expense (2)	57,767			56,842			925			1.6	%
Depreciation and amortization	103,687			78,973			24,714			31.3	%

Impairment expense	—			57,454			(57,454)			(100.0)	%
Loss on disposal of assets	25,145			22,947			2,198			9.6	%
Interest expense	1,847			803			1,044			130.0	%
Other expense (income)	3,632			(10,364)			13,996			135.0	%
Income tax expense (benefit)	20,474			(3,932)			24,406			620.7	%
Net income (loss)	$	67,990		$	(21,043)		$	89,033		423.1	%

Adjusted EBITDA (3)	$	231,978		$	142,480		$	89,498		62.8	%
Adjusted EBITDA Margin (3)	27.0		%	23.8		%	3.2		%	13.4	%

Completion Services segment results of operations:
Revenue	$	858,819		$	586,557		$	272,262		46.4	%
Cost of services	$	578,277		$	406,255		$	172,022		42.3	%
Adjusted EBITDA (3)	$	231,978		$	141,814		$	90,164		63.6	%
Adjusted EBITDA Margin (4)	27.0		%	24.2		%	2.8		%	11.6	%

(1)Exclusive of depreciation and amortization.

(2)Inclusive of stock-based compensation.

(3)For definitions of the non-GAAP financial measures of Adjusted EBITDA and Adjusted EBITDA margin and reconciliation of Adjusted EBITDA to our most directly comparable financial measures calculated in accordance with GAAP, please read "How We Evaluate Our Operations". Included in our Adjusted EBITDA is reservation ~~and idle~~ fees of $~~20.3 million~~0 and ~~$5.3~~$13.5 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, respectively.

~~-27-~~-32-

~~Nine~~

Six Months Ended ~~September~~June 30, ~~2022~~2023 Compared to the ~~Nine~~Six Months Ended ~~September~~June 30, ~~2021~~2022

Revenues.R~~evenue~~s Revenues increased ~~48.1%~~43.7%, or ~~$302.3~~$261.1 million, to ~~$930.8~~$858.8 million during the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$628.4~~$597.8 million during the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. Our ~~pressure pumping~~Completion Services segment revenues increased ~~48.6%~~46.4%, or ~~$300.0~~$272.3 million, for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. The increases were primarily attributable to the significant increase in our existing and new customers' activity levels, resulting in higher demand for ~~pressure pumping~~completion services, improved pricing and ~~improved pricing.~~the addition of wireline operations. The addition of wireline operations contributed $126.4 million of the increase in total revenues. As a result of our customers' increased activity levels, our effectively utilized hydraulic fracturing fleet count rose to approximately ~~14.4~~16 active fleets during the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, from approximately ~~12.4~~14 active fleets for the ~~nine~~six months ended ~~September~~June 30, ~~2021. Included in our~~2022. Our revenue for the ~~nine~~six months ended ~~September~~June 30, 2023 and 2022, ~~and 2021 was revenue generated from~~included reservation ~~and idle~~ fees charged to ~~our~~a customer of approximately ~~$20.3 million~~$0 and ~~$5.3~~$13.5 million, respectively.

Revenues from services other than ~~pressure pumping increased 20.5%~~Completion Services decreased 100.0%, or ~~$2.3~~$11.2 million, to ~~$13.4 million~~$0 for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to $11.2 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. The ~~increase~~decrease in revenue from services other than ~~pressure pumping~~Completion Services was ~~primarily attributable~~due to ~~improved pricing and~~ the ~~increase in utilization experienced by~~discontinuation of our coiled tubing operations ~~which was driven by increased E&P completions activity.~~effective September 1, 2022.

Cost of Services. Cost of services increased ~~34.8%~~39.0%, or ~~$165.3~~$162.2 million, to ~~$640.2~~$578.3 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$474.9~~$416.1 million during the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. Cost of services in our ~~pressure pumping~~Completion Services segment increased ~~$162.3~~$172.0 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. These increases were primarily attributable to ~~the significantly~~ increased activity levels resulting from the increased demand for our services as compared to 2022, the addition of wireline operations and the impact of general cost inflation. The addition of wireline operations resulted in $83.1 million increase in our cost of services. As a percentage of ~~pressure pumping~~Completion Services segment revenues (including reservation ~~and idle~~ fees), ~~pressure pumping~~Completion Services cost of services was ~~68.3%~~67.3% for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~75.2%~~69.3% for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. Excluding reservation ~~and idle~~ fees revenue of ~~$20.3 million~~$0 and ~~$5.3~~$13.5 million recorded during the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 and ~~2021,~~2022, respectively, our ~~pressure pumping~~Completion Services cost of services as a percentage of ~~pressure pumping~~Completion Services revenues decreased to ~~69.8%~~67.3% during the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~75.9%~~70.9% for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. The decrease in the percentages was primarily a result of increased operational efficiencies, ~~reduction in operational downtime~~operating scale from higher utilization and improved customer pricing, ~~across our customer base.~~partially offset by costs of $17.4 million associated with the replacement of fluid ends during the six months ended June 30, 2023. Fluid ends were capitalized and depreciated in 2022. Effective January 1, 2023, the Company commenced expensing fluid ends as part of cost of services rather than capitalizing fluid ends as part of property and equipment as a result of the change in estimated useful life.

General and Administrative Expenses. General and administrative expenses increased ~~43.9%~~1.6%, or ~~$26.0~~$0.9 million, to ~~$85.0~~$57.8 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$59.1~~$56.8 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. The net increase was primarily attributable to an(i) a $3.9 million increase ~~during 2022~~ in payroll and related expenses, (ii) a $1.3 million increase in consulting fees, (iii) a $2.4 million increase in travel, advertising expenses, and other office utilities, and (iv) a $3.3 million increase in other general and administrative expenses, and partially offset by (i) ~~non-recurring legal expenses (net of insurance recoveries) increased by $12.8~~a $7.5 million ~~which were primarily~~decrease in ~~connection with shareholder litigation and settlement with a vendor, (ii)~~ stock-based compensation expense ~~of $9.7 million, which was primarily attributable to the non-recurring incremental stock-based compensation associated with~~driven by the acceleration of stock awards during the six months ended June 30, 2022 upon resignation of a former ~~executive,~~executive; and ~~(iii) consulting~~(ii) a $2.5 million decrease in legal settlements.

Excluding nonrecurring and ~~professional fees of approximately $4.5~~non-cash items (stock-based compensation, insurance reimbursements, legal settlements, transaction expenses, retention bonuses and severance expenses), general and administrative expenses were $48.6 million ~~which was partially offset by a net decrease of approximately $1.0~~during the six months ended June 30, 2023, as compared to $39.1 million ~~in other general administrative expenses.~~during the six months ended June 30, 2022.

Depreciation and Amortization. Depreciation and amortization ~~decreased 6.5%~~increased 31.3%, or ~~$6.5~~$$24.7 million, to ~~$93.7~~$103.7 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$100.3~~$79.0 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. The ~~decrease~~increase was primarily attributable to (i) assets placed into service since June 30, 2022, (ii) reduction of the ~~decrease in our fixed asset base, partly attributable to the disposal~~estimated useful life of certain ~~fixed~~equipment in 2023, and (iii) the addition of wireline assets ~~during the period.~~which included $6.1 million of depreciation and $2.9 million of amortization of intangible assets.

Impairment Expense. ~~During the nine months ended September 30, 2022, we recorded $57.5 millionin connection with the impairment of~~ ~~our~~ ~~DuraStim®~~ ~~assets.~~ There was no impairment expense during the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2023. During the six months ended June 30, 2022, we recorded a loss of $57.5 million in connection with the impairment of our DuraStim® electric powered hydraulic fracturing equipment.

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Loss on Disposal of Assets. Loss on the disposal of assets increased ~~85.8%~~9.6%, or ~~$34.7~~$2.2 million, to ~~$75.2~~$25.1 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$40.5~~$22.9 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~ 2022. The increase was primarily attributable to losses incurred from the ~~divestiture~~decommissioning/conversion of ~~our coiled tubing operations~~certain hydraulic fracturing equipment and the ~~significant increase~~write-off of certain hydraulic fracturing equipment as a result of an accidental fire at a wellsite in ~~our utilization levels,~~March 2023, partially offset by the Company expensing costs associated with replacement of fluid ends as part of cost of services resulting ~~in an increase in the operational intensity on our pressure pumping equipment.~~ ~~Upon sale or retirement of property and equipment, including replaced fluid and power ends, the cost and related accumulated depreciation of such assets or components are removed~~ from the ~~balance sheet and the net amount is recognized as loss on disposal of assets.~~change in estimated useful life effective January 1, 2023.

Interest Expense. ~~There was no significant change in interest expense.~~ Interest expense ~~slightly~~ increased to ~~$1.0~~$1.8 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$0.5~~$0.8 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. The increase was primarily attributable to outstanding borrowings under our ABL Credit Facility during the ~~partial write down of unamortized capitalized loan origination cost in connection with~~six months ended June 30, 2023, compared to no outstanding borrowings during the ~~modification to our credit facility.~~six months ended June 30, 2022.

Other ~~Income.~~Expense (Income). Other ~~income increased 727.6%, or $8.6 million, to $9.7~~expense was approximately $3.6 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to ~~$1.2~~other income of $10.4 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021. The increase was~~2022. Other expense during the six months ended June 30, 2023 is primarily ~~attributable to the net~~

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~~refund to the Company~~comprised of $10.7 million from sales, excise and use taxes, $2.7 million of non-cash income from equipment parts inventory received from our equipment manufacturer as settlement of our warranty claims, partially offset by a ~~$3.3~~$3.9 million unrealized loss on short-term ~~investment~~investment. Other income during the six months ended June 30, 2022 was primarily comprised of a $10.7 million net tax refund of sales, excise and ~~other expense relating to our lender's commitment fees.~~use taxes.

Income Taxes. ~~For the nine months ended September 30, 2022, the Company has utilized the discrete effective tax rate method as allowed by ASC 740-270-30-18,~~ ~~Income Taxes - Interim Reporting~~ ~~to calculate its interim tax provision. The discrete method treats the year-to-date period as if it was the annual period and determines the~~Total income tax expense ~~or benefit on that basis. The Company believes that, at this time, the use of this discrete method is more appropriate than the annual effective tax rate method~~ was ~~the annual effective tax rate is not reliable because small changes in estimated “ordinary” income would result in significant changes in the estimated annual effective tax rate.~~ ~~Total income tax benefit was approximately $1.2~~$20.5 million resulting in an effective tax rate of ~~9.6%~~23.1% for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, as compared to income tax benefit of ~~$11.6~~$3.9 million or an effective tax rate of ~~25.5%~~15.7% for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. The change in income tax ~~benefit~~expense (benefit) recorded during the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, compared to ~~that during~~ the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, is primarily attributable to the difference in the estimated pre-tax ~~loss in 2022,~~income (loss) for 2023, as compared to ~~2021. Furthermore, the change in the effective tax rate of 9.6% from~~ ~~25.5% was due to nondeductible expenses and discrete items such as stock compensation expense recorded during the nine months ended September 30, 2021.~~2022.

Liquidity and Capital Resources

Our liquidity is currently provided by (i) existing cash balances, (ii) operating cash flows and (iii) borrowings under our ABL Credit Facility (as defined below). Our cash is primarily used to fund our operations, support growth opportunities, fund our share repurchases under our share repurchase program and satisfy future debt ~~payments, if any.~~payments. Our restricted cash, which was received from a customer, will be used solely for the construction or operation of certain electric hydraulic fracturing equipment. Our Borrowing Base (as defined below), as redetermined monthly, is tied to ~~85.0%~~the sum of 85% to 90% of monthly eligible accounts ~~receivable.~~receivable and 80% of eligible unbilled accounts (up to a maximum of 25% of the Borrowing Base), in each case, depending on the credit ratings of our accounts receivable counterparties, less customary reserves. Changes to our operational activity levels and our customers' credit ratings have an impact on our total eligible accounts receivable, which could result in significant changes to our Borrowing Base and therefore, our availability under our ABL Credit Facility.

We received advance payments from a customer for our services, and the amount outstanding in connection with the advance payments as of June 30, 2023 was $20.3 million, which includes restricted cash of $12.2 million.

As of ~~September~~June 30, ~~2022, we had no~~2023, our borrowings under our ABL Credit Facility were $60.0 million and our total liquidity was approximately ~~$154.5~~$169.6 million, consisting of cash, ~~and~~ cash equivalents and restricted cash of ~~$43.2~~$62.1 million and ~~$111.3~~$107.5 million of availability under our ABL Credit Facility.

In July 2023, the Company repaid $15.0 million of outstanding borrowings under the ABL Credit Facility. As of ~~October~~July 31, ~~2022,~~2023, our ~~borrowing~~borrowings under our ABL Credit Facility ~~was $30.0~~were $45.0 million and our total liquidity was approximately ~~$185.6~~$175.2 million, consisting of cash, ~~and~~ cash equivalents and restricted cash of ~~$88.3~~$62.9 million and ~~$97.3~~$112.3 million of ~~remaining~~ availability under our ABL Credit Facility.

~~In 2020, when demand for our services was significantly depressed following~~

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On May 17, 2023, the ~~rapidly rising health crisis associated~~Board authorized and the Company announced a share repurchase program that allows the Company to repurchase up to $100 million of the Company's common stock beginning immediately and continuing through and including May 31, 2024. The shares may be repurchased from time to time in open market transactions, block trades, accelerated share repurchases, privately negotiated transactions, derivative transactions or otherwise, certain of which may be made pursuant to a trading plan meeting the requirements of Rule 10b5-1 under the Exchange Act, as amended, in compliance with applicable state and federal securities laws. The timing, as well as the number and value of shares repurchased under the program, will be determined by the Company at its discretion and will depend on a variety of factors, including management's assessment of the intrinsic value of the Company's common stock, the market price of the Company's common stock, general market and economic conditions, available liquidity, compliance with the ~~COVID-19 pandemic~~Company's debt and other agreements, applicable legal requirements, and other considerations. The Company is not obligated to purchase any shares under the repurchase program, and the ~~energy industry disruptions,~~program may be suspended, modified, or discontinued at any time without prior notice. The Company expects to fund the repurchases using cash on hand and expected free cash flow to be generated through May 2024. During the three months ended June 30, 2023, the Company ~~experienced a significant decrease~~repurchased and retired 2.3 million shares of common stock for an aggregate of $17.5 million, an average price per share of $7.63 including commissions, under the repurchase program. As of June 30, 2023, $82.5 million remained authorized for future repurchases of common stock under the repurchase program.

As part of our real estate consolidation strategy, on July 14, 2023 we entered into an agreement to sell our corporate office building and the associated real property, which were included in ~~its liquidity. However,~~our Completion Services segment. We expect to receive estimated cash proceeds of $5.0 million, subject to customary closing requirements. We plan to lease office space in connection with the ~~gradual recovery in the energy industry and the reduced impact~~relocation of ~~the COVID-19 pandemic, we have seen improvements in the demand for~~ our services and pricing, and our liquidity position gradually improved. However, we expect our overall liquidity to decline if we make additional or accelerate our capital investments. Moreover, the current market conditions may be impacted by increasing interest rates and potential economic slowdown or a new outbreak of a COVID-19 variant or other health crisis, which could negatively impact our future operations, revenue, profitability and cash flows.

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

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

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

~~-29-~~

~~plus the applicable margin, which ranged from 1.75% to 2.25% for LIBOR loans and 0.75% to 1.25% for base rate loans, with a LIBOR floor of zero.~~

~~Effective April 13, 2022,~~ ~~the Company entered into an amendment and restatement of its revolving credit facility (as amended and restated, "ABL Credit Facility"). The ABL Credit Facility decreased the borrowing capacity to $150.0 million (subject to the Borrowing Base limit), with a maturity date extended to April 13, 2027. The ABL Credit Facility has a borrowing base of 85% to 90%, dep~~ending on the credit ratings of our accounts receivable counterparties, of monthly eligible accounts receivable less customary reserves (the "Borrowing Base"), as redetermined monthly. The Borrowing Base as of ~~September 30, 2022,~~ was approximately $116.4 million. The ABL Credit Facility includes a springing fixed charge coverage ratio to apply when excess availability is less than the greater of (i) 10% of the lesser of the facility size or the Borrowing Base or ~~(ii) $10.0 million.~~ Under this facility we are required to comply, subject to certain exceptions and materiality qualifiers, with certain customary affirmative and negative covenants, including, but not limited to, covenants pertaining to our ability to incur liens, indebtedness, changes in the nature of our business, mergers and other fundamental changes, disposal of assets, investments and restricted payments, amendments to our organizational documents or accounting policies, prepayments of certain debt, dividends, transactions with affiliates, and certain other activities. Borrowings under the ABL Credit Facility are secured by a first priority lien and security interest in substantially all assets of the Company. Borrowings under the ABL Credit Facility accrue interest based on a three-tier pricing grid tied to availability, and we may elect for loans to be based on either the Secured Overnight Financing Rate ("SOFR") or the base rate, plus the applicable margin, ~~which ranges from 1.50% to 2.00% for SOFR loans and 0.50% to 1.00% for base rate loans.~~

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

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Capital Requirements, Future Sources and Use of Cash and Contractual Obligations

Capital expenditures incurred were ~~$115.1~~$115.2 million during the three months ended June 30, 2023, as compared to $89.1 million during the three months ended June 30, 2022. ~~September 30, 2022, as compared to $53.2 million during the three months ended September 30, 2021.~~ The significant portion of our total capital expenditures incurred were ~~comprised~~maintenance capital expenditures and conversion of ~~primarily maintenance and DGB conversion capital expenditures.~~our hydraulic fracturing equipment to lower emissions equipment.

Our future material use of cash will be to fund our capital expenditures. We may also use material amounts of cash to repurchase shares under our share repurchase program. Capital expenditures for ~~2022~~2023 are projected to be primarily related to ~~maintenance~~ capital expenditures to ~~support~~extend the useful life of our existing ~~pressure pumping~~completion services assets, costs to convert or rebuild some existing equipment to lower emissions ~~pressure pumping~~ equipment, strategic purchases and other ancillary equipment purchases, subject to market conditions and customer ~~demand.~~demand and potential strategic acquisitions. Our future capital expenditures depend on our projected operational activity, emission requirements and planned conversions to lower emissions equipment, among other factors, which could vary significantly throughout the year. We could incur significant additional capital expenditures if our projected activity levels increase during the course of the year, inflation and supply chain tightness continue to adversely impact our operations or we invest in new or different lower emissions equipment. The Company will continue to evaluate the emissions profile of its ~~fleet~~equipment over the coming years and may, depending on market conditions, convert or retire additional conventional Tier II equipment in favor of lower emissions equipment. The Company’s decisions regarding the retirement or conversion of equipment or the addition of lower emissions equipment will be subject to a number of factors, including (among other factors) the availability of equipment, including parts and major components, supply chain disruptions, prevailing and expected commodity prices, customer demand and requirements and the Company’s evaluation of projected returns on conversion or other capital expenditures. Depending on the impacts of these factors, the Company may decide to retain conventional equipment for a longer period of time or accelerate the retirement, replacement or conversion of that equipment.

We anticipate our capital expenditures will be funded by existing cash, cash flows from operations, and if needed, borrowings under our ABL Credit Facility. Our cash flows from operations will be generated from services we provide to our customers. In addition, our cash flows could be improved by prepayments received from certain customers in connection with our ~~pressure pumping~~completion services contractual arrangements, as applicable.

~~In August 2022, we~~

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We entered into a contractual ~~arrangement~~arrangements with our equipment ~~manufacturer~~manufacturers to purchase and convert ~~additional~~ Tier IV DGB equipment, with a total cost of ~~approximately $43.0 million. In August 2022, we~~approximately $16.4 million for the remainder of 2023. We entered into ~~the Electric~~a sand purchase agreement with a supplier that will expire on December 31, 2024 with a remaining take-or-pay commitment of approximately $29.2 million. We also entered into three-year equipment leases (the "Electric Fleet ~~Lease to lease~~Leases") for a total of four electric hydraulic fracturing ~~pumps~~fleets with capacity of 60,000 HHP per fleet, which contains options to extend the lease or purchase the equipment at the end of the lease. The lease payments ~~are expected to~~will commence when ~~the Company takes~~we take possession of the electric hydraulic fracturing ~~pumps during~~fleets. We currently expect to take delivery of most of the electric hydraulic fracturing fleets in the second half of 2023. The total estimated contractual commitment in connection with the Electric Fleet ~~Lease~~Leases is approximately ~~$49.3~~$96.4 million, which ~~includes~~excludes the cost associated with the option to purchase the equipment at the end of ~~the~~each lease.

~~On November 1, 2022, we~~ We also entered into a ~~purchase and sale agreement with New Silvertip Holdco, LLC, to purchase 100% of equity interest of Silvertip Completion Services Operating, LLC (the "Silvertip Acquisition"~~three year ("Power Equipment Lease")~~. Under the terms of the purchase agreement, we acquired, subject to exceptions in the Silvertip Acquisition, 100% of Silvertip Completion Services Operating, LLC equity interest~~ for ~~a consideration of both cash and shares of our Company.~~certain power generation equipment. The total ~~consideration paid consisted of 10.1 million shares of our Company, cash of $30.0 million, and certain other closing and transaction costs.~~estimated contractual commitment in connection with the Power Equipment Lease is approximately $59.6 million.

In the normal course of business, we enter into various contractual obligations and incur expenses in connection with routine growth, conversion and maintenance capital expenditures that impact our future liquidity. There were no other known future material contractual obligations as of ~~September~~June 30, ~~2022~~2023.

Cash, Restricted Cash and Cash Flows

The following table sets forth the historical cash flows for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, and ~~2021:~~2022:

Nine Months Ended September 30,
(in thousands) 2022 2021
Net cash provided by operating activities $ 174,951 $ 109,259
Net cash used in investing activities $ (239,957) $ (85,549)
Net cash used in financing activities $ (3,704) $ (7,881)

~~-31-~~


	Six Months Ended June 30,
(in thousands)	2023		2022

Net cash provided by operating activities	$	187,014	$	103,308
Net cash used in investing activities	$	(221,731)	$	(141,568)
Net cash provided by (used in) financing activities	$	7,968	$	(3,869)

Cash Flows From Operating Activities

Net cash provided by operating activities was ~~$175.0~~$187.0 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, compared to ~~$109.3~~$103.3 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. The net increase of approximately ~~$65.7~~$83.7 million was primarily due to the improvement in our net income, resulting from the significant increase in our existing and new customers' activity levels, resulting in higher demand for completion services, increased operational efficiencies and ~~improved pricing resulting from the~~reduction in operational downtime. The increase in ~~the demand for our services, driven~~cash provided by ~~higher crude oil prices, net sales tax refund received, and partially offset with the~~operating activities was also impacted by timing of our receivable collections offrom our ~~receivables from~~ customers and payments to ~~vendors.~~our vendors, partially offset by an increase in inventories.

Cash Flows From Investing Activities

Net cash used in investing activities increased to ~~$240.0~~$221.7 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, from ~~$85.5~~$141.6 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. The increase was primarily attributable to maintenance capital expenditures and our investment in lower emissions Tier IV DGB equipment (conversion of Tier II equipment to Tier IV DGB equipment and ~~increased cost to rebuild a portion of~~new Tier IV DGB equipment). During the six months ended June 30, 2023, we have paid approximately $60.5 million in connection with our Tier IIIV DGB and electric equipment.

Cash Flows From Financing Activities

Net cash ~~used in~~provided by financing activities ~~decreased to $3.7~~was $8.0 million for the ~~nine~~six months ended ~~September~~June 30, ~~2022, from $7.9~~2023, compared to net cash used of $3.9 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022. The net ~~decrease~~increase in cash ~~used in~~flows from financing activities during the ~~nine~~six months ended ~~September~~June 30, ~~2022,~~2023, was primarily ~~a result~~driven by borrowings of $30.0 million under our ABL Credit Facility (as defined below), partially offset by share repurchases of $17.5 million during the ~~reduction~~six months ended June 30, 2023 and an increase in ~~the amount of net settlement of equity awards and no repayments of insurance financing in 2022,~~debt issuance costs paid compared to the ~~nine~~six months ended ~~September~~June 30, ~~2021.~~2022.

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Credit Facility and Other Financing Arrangements

Our revolving credit facility, as amended and restated in April 2022, prior to giving effect to the amendment to the revolving credit facility in June 2023, had a total borrowing capacity of $150.0 million. The revolving credit facility had a borrowing base of 85% to 90%, depending on the credit ratings of our accounts receivable counterparties, of monthly eligible accounts receivable less customary reserves. The revolving credit facility included a springing fixed charge coverage ratio to apply when excess availability was less than the greater of (i) 10% of the lesser of the facility size or the borrowing base or (ii) $10.0 million. Under the revolving credit facility we were 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.

Effective June 2, 2023, the Company entered into an amendment to its amended and restated revolving credit facility the revolving credit facility (as amended and restated in April 2022, as amended in June 2023 and as may be amended further, "ABL Credit Facility"). The amendment increased the borrowing capacity under the ABL Credit Facility to $225.0 million (subject to the Borrowing Base (as defined below) limit), and extended the maturity date to June 2, 2028. The ABL Credit Facility has a borrowing base of the sum of 85% to 90% of monthly eligible accounts receivable and 80% of eligible unbilled accounts (up to a maximum of 25% of the Borrowing Base) less customary reserves (the "Borrowing Base"), in each case, depending on the credit ratings of our accounts receivable counterparties, as redetermined monthly. The Borrowing Base as of June 30, 2023, was approximately $173.5 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) $15.0 million. Under the ABL Credit 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.

Off-Balance Sheet Arrangements

We had no off-balance sheet arrangements as of ~~September~~June 30, ~~2022.~~2023.

Critical Accounting Policies and Estimates

~~There~~Other than the change in accounting estimate discussed in Note 1 of our Condensed Consolidated Financial Statements (Unaudited), there have been no material changes during the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 to the methodology applied by our management for critical accounting policies previously disclosed in our Form 10-K. Please refer to Part II, Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies and Estimates" in our Form 10-K for a discussion of our critical accounting policies and estimates.

Recently Issued Accounting Standards

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

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As of ~~September~~June 30, ~~2022,~~2023, 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.

~~-32-~~-37-

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

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

As required by Rule 13a-15(b) under the Exchange Act, we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this quarterly report. Based upon that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective at the reasonable assurance level as of ~~September~~June 30, ~~2022.~~2023.

Changes in Internal Control over Financial Reporting

There were no changes in our system of internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the quarter ended ~~September~~June 30, ~~2022~~2023 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

~~-33-~~-38-

PART II – OTHER INFORMATION

ITEM 1. Legal Proceedings

See ~~“Note 10~~“Note 13 – Commitments and Contingencies” in the Notes to Condensed Consolidated Financial Statements for further information.

ITEM 1A. Risk Factors

Other than as set forth below, there have been no material changes to the risk factors disclosed in Part I, Item 1A. of our Form 10-K.

~~The Inflation Reduction Act of 2022~~Adverse developments affecting the financial services industry, such as events or concerns involving liquidity, defaults or non-performance by financial institutions or transactional counterparties, could ~~accelerate the transition to a low carbon economy and could impose new costs on our customers’ operations.~~

In August 2022, President Biden signed the Inflation Reduction Act of 2021 (“IRA 2022”) into law. The IRA 2022 contains hundreds of billions in incentives for the development of renewable energy, clean hydrogen, clean fuels, electric vehicles and supporting infrastructure and carbon capture and sequestration, amongst other provisions. These incentives could further accelerate the transition of the economy away from the use of fossil fuels towards lower- or zero-carbon emissions alternatives, which could decrease demand for oil and gas and consequently adversely affect the Company’s current and projected business operations and its financial condition and results of operations.

Events involving limited liquidity, defaults, non-performance or other adverse developments that affect financial institutions, transactional counterparties or other companies in the financial services industry or the financial services industry generally, concerns or rumors about such events or other similar risks, have in the past and may in the future lead to acute or market-wide liquidity problems. In addition, if any of the Company’s customers, suppliers or other business counterparties are unable to access funds held by such a financial institution, such parties’ ability to pay their obligations to the Company or to enter into new commercial arrangements requiring additional payments to the Company could be adversely affected.

Inflation and rapid increases in interest rates have led to a decline in the trading value of previously issued government securities with interest rates below current market interest rates. Although the U.S. Department of Treasury, Federal Deposit Insurance Corporation ("FDIC") and Federal Reserve Board have announced a program to mitigate the risk of potential losses on the sale of such instruments, widespread demands for customer withdrawals or other needs of financial institutions for immediate liquidity may exceed the capacity of such program. Additionally, the Company maintains cash balances at third-party financial institutions in excess of the FDIC standard insurance limits, and there is no guarantee that the U.S. Department of Treasury, FDIC and Federal Reserve Board will provide access to uninsured funds in the future in the event of the closure of such banks or financial institutions, or that they would do so in a timely fashion.

Access to funding sources and other credit arrangements in amounts adequate to finance the Company’s business operations could be significantly impaired by the foregoing factors that affect the Company, any financial institutions with which the Company enters into credit agreements or arrangements directly, or the financial services industry or economy in general. These factors could include, among others, events such as liquidity constraints or failures, the ability to perform obligations under various types of financial, credit or liquidity agreements or arrangements, disruptions or instability in the financial services industry or financial markets, or concerns or negative expectations about the prospects for companies in the financial services industry.

The results of events or concerns that involve one or more of these factors could include a variety of material and adverse impacts on the Company’s current and projected business operations and the Company’s financial condition and results of operations. These risks include, but may not be limited to, the following:

•delayed access to deposits or other financial assets or the uninsured loss of deposits or other financial assets;

•inability to enter into credit facilities or other working capital resources;

•potential or actual breach of contractual obligations that require the Company to maintain letters of credit or other credit support arrangements; or

•termination of cash management arrangements and/or delays in accessing or actual loss of funds subject to cash management arrangements.

In addition, investor concerns regarding the U.S. or international financial systems could result in less favorable commercial financing terms, including higher interest rates or costs and tighter financial and operating covenants, or systemic limitations on access to credit and liquidity sources, thereby making it more difficult for the Company to acquire financing on acceptable terms or at all. Any decline in available funding or access to cash and liquidity resources could, among other risks, adversely impact the Company’s ability to meet operating expenses or other obligations, financial or otherwise, result in breaches of the Company’s financial and/or contractual obligations, or result in violations of federal or state wage and hour laws. In addition, any further deterioration in the macroeconomic economy or financial services industry could lead to losses or defaults by the Company’s customers, vendors or suppliers. Any of these impacts, or any other impacts resulting from the factors described

-39-

above or other related or similar factors, could have material adverse impacts on the Company’s liquidity and their current and/or projected business operations and financial condition and results of operations.

There can be no assurance that our recently announced share repurchase program will be fully consummated or that such program will enhance the long-term value of our ~~customers, thereby reducing demand~~share price.

On May 17, 2023, the Company's Board approved a share repurchase program that allows the Company to repurchase up to $100 million of the Company's common stock through and including May 31, 2024. There is no obligation for the Company to continue to repurchase or to repurchase any specific dollar amount of stock. The timing, as well as the number and value of shares repurchased under the program, will be determined by the Company at its discretion and will depend on a variety of factors, including management's assessment of the intrinsic value of the Company's common stock, the market price of the Company's common stock, general market and economic conditions, available liquidity, compliance with the Company's debt and other agreements, applicable legal requirements, and other considerations. The Company is not obligated to purchase any shares under the repurchase program, and the program may be suspended, modified, or discontinued at any time without prior notice. The repurchase program could affect the price of our ~~services.~~stock and increase volatility in the market. We cannot guarantee that the repurchase program will be fully consummated or that such program will enhance the long-term value of our share price. In addition, the IRA 2022 imposes the first ever federal fee on the emission of greenhouse gases through a methane emissions charge. The IRA 2022 amends the federal Clean Air Act to impose a fee on the emission of methane from sources required to report their GHG emissionsrepurchase regulations and taxes may add additional payment burden to the ~~U.S. Environmental Protection Agency, including those sources~~Company from our share repurchase program. For example, the Biden administration has proposed increasing the amount of the excise tax from 1% to 4%; however, it is unclear whether such a change in the onshore petroleum and natural gas production and gathering and boosting source categories. The methane emissions charge would start in calendar year 2024 at $900 per ton of methane, increase to $1,200 in 2025, and be set at $1,500 for 2026 and each year after. Calculationamount of the ~~fee is based on certain thresholds established in the IRA 2022. The methane emissions charge~~excise tax will be enacted and, if enacted, how soon any such change could ~~increase our customers’ operating costs and adversely affect their businesses, thereby reducing demand for our services.~~take effect.

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

~~None.~~Share Repurchase Program

The following sets forth information with respect to our repurchases of shares of common stock during the three months ended June 30, 2023:


Period	Total number of shares purchased	Average price paid per share (2)		Total number of shares purchased as part of publicly announced plans or programs (1)	Approximate dollar value of shares that may yet be purchased under the plans or programs (1)
May 17, 2023 to May 31, 2023	609,703	$	7.37	609,703	$	95,506,752
June 1, 2023 to June 30, 2023	1,678,996	$	7.73	1,678,996	$	82,529,600
Total	2,288,699	$	7.63	2,288,699	$	82,529,600

(1)On May 17, 2023, the Board authorized and the Company announced a share purchase program that allows the Company to repurchase up to $100 million of the Company's common stock beginning immediately and continuing through and including May 31, 2024. The shares may be repurchased from time to time in open market transactions, block trades, accelerated share repurchases, privately negotiated transactions, derivative transactions or otherwise, certain of which may be made pursuant to a trading plan meeting the requirements of Rule 10b5-1 under the Exchange Act, as amended, in compliance with applicable state and federal securities laws.

(2)The average price paid per share includes commissions.

ITEM 3. Defaults Upon Senior Securities

None.

ITEM 4. Mine Safety Disclosures

Not applicable.

ITEM 5. Other Information

~~None.~~During the three months ended June 30, 2023, no director or officer of the Company adopted, modified or terminated any "Rule 10b5-1 trading arrangement" or "non-Rule 10b5-1 trading arrangement" within the meaning of Item 408 of Regulation S-K.

~~-34-~~-40-

ITEM 6. Exhibits

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


3.1						Amended and Restated Certificate of Incorporation of ProPetro Holding Corp. dated as of June 19, 2019 (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K, dated June 19, 2019).
3.2						Amended and Restated Bylaws of ProPetro Holding Corp. (incorporated by reference to Exhibit 3.2 to the Company's Current Report on Form 8-K, dated June 19, 2019).
3.3						Certificate of Designations of Series B Junior Participating Preferred Stock of ProPetro Holding Corp. (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K, dated April 14, 2020).
10.1						Amendment No. 1 to Amended and Restated Credit Agreement, dated as of June 2, 2023, by and among ProPetro Holding Corp., and ProPetro Services, Inc., the Incremental Lenders and each existing Lender party thereto as a Consenting Lender and Barclays Bank PLC, as Agent (incorporated by reference to Exhibit 10.1 of the Company's Current Report on Form 8-K, dated June 2 , 2023).
10.2#						Amended and Restated ProPetro Holding Corp. 2020 Long Term Incentive Plan (incorporated by reference to Exhibit 10.1 to the Company's Current Report o n Form 8-K, dated May 1 1 , 2023).
31.1*						Certification of Principal Executive Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Exchange Act Rules, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*						Certification of Principal Financial Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Exchange Act Rules, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**						Certification of Principal Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted by Section 906 of the Sarbanes-Oxley Act of 2002.
32.2**						Certification of Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted by Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS*						XBRL Instance Document
101.SCH*						XBRL Taxonomy Extension Schema Document
101.CAL*						XBRL Taxonomy Extension Calculation Linkbase Document
101.LAB*						XBRL Taxonomy Extension Label Linkbase Document
101.PRE*						XBRL Taxonomy Extension Presentation Linkbase Document
101.DEF*						XBRL Taxonomy Extension Definition Linkbase Document
104*						Cover Page Interactive Data File - the cover page interactive data file does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document


*			Filed herewith.
**			Furnished herewith.
#			Compensatory plan, contract or arrangement.

~~-35-~~-41-

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:

~~November~~August 3, ~~2022~~2023

By:

/s/ Samuel D. Sledge

Samuel D. Sledge

Chief Executive Officer and Director

(Principal Executive Officer)

By:

/s/ David S. Schorlemer

David S. Schorlemer

Chief Financial Officer

(Principal Financial Officer)

By:

/s/ Elo Omavuezi

Elo Omavuezi

Chief Accounting Officer

(Principal Accounting Officer)

~~-36-~~-42-


	Three Months Ended September 30, 2022
	Pressure Pumping		All Other		Total
Service revenue	$	330,780	$	2,234	$	333,014
Adjusted EBITDA	$	102,550	$	(12,550)	$	90,000
Depreciation and amortization	$	29,736	$	681	$	30,417
Capital expenditures	$	112,865	$	2,258	$	115,123
Total assets at September 30, 2022	$	1,091,796	$	51,810	$	1,143,606


	Three Months Ended September 30, 2021
	Pressure Pumping		All Other		Total
Service revenue	$	245,641	$	4,458	$	250,099
Adjusted EBITDA	$	53,975	$	(11,877)	$	42,098
Depreciation and amortization	$	32,536	$	995	$	33,531
Capital expenditures	$	52,904	$	300	$	53,204
Total assets December 31, 2021	$	1,023,037	$	38,199	$	1,061,236