ProPetro Holding Corp. - Quarter Report: 2018 June (Form 10-Q)

Large accelerated filer

Accelerated filer

Non-accelerated filer

ý (Do not check if a smaller reporting company)

Smaller reporting company

Emerging growth company

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

______________________________

FORM 10-Q

______________________________



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

For the quarterly period ended June 30, 2018



¨	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, Bldg. B

Midland, Texas 79701

(Address of principal executive offices)

(432) 688-0012

(Registrant’s telephone number, including area code)

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 ý No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files). Yes ý No ¨

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

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. ý

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

The number of the registrant’s common shares, par value $0.001 per share, outstanding at August 1, 2018, was 83,543,646

PROPETRO HOLDING CORP. AND SUBSIDIARY

TABLE OF CONTENTS



		Page
PART I – FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
	Condensed Consolidated Balance Sheets as of June 30, 2018 and December 31, 2017	1
	Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2018 and 2017	2
	Condensed Consolidated Statement of Shareholders' Equity for the six months ended June 30, 2018	3
	Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2018 and 2017	4
	Notes to Condensed Consolidated Financial Statements	5
	Cautionary Note Regarding Forward-Looking Statements	17
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	18
	Results of Operations	22
	Liquidity and Capital Resources	26
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	28
Item 4.	Controls and Procedures	28
PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	29
Item 1A.	Risk Factors	29
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	29
Item 3.	Defaults Upon Senior Securities	29
Item 4.	Mine Safety Disclosures	29
Item 5.	Other Information	29
Item 6.	Exhibits	30
	Signatures	31

-i-

PROPETRO HOLDING CORP. AND SUBSIDIARY

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)

(Unaudited)

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS



	June 30, 2018			December 31, 2017

ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	27,103		$	23,949
Accounts receivable - net of allowance for doubtful accounts of $457 and $443, respectively	316,498			199,656
Inventories	7,744			6,184
Prepaid expenses	3,451			5,123
Other current assets	1,131			748
Total current assets	355,927			235,660
PROPERTY AND EQUIPMENT - Net of accumulated depreciation	551,253			470,910
OTHER NONCURRENT ASSETS:
Goodwill	9,425			9,425
Intangible assets - net of amortization	157			301
Deferred revenue rebate - net of amortization	—			615
Other noncurrent assets	2,253			2,121
Total other noncurrent assets	11,835			12,462
TOTAL ASSETS	$	919,015		$	719,032
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	268,562		$	211,149
Accrued and other current liabilities	26,329			16,607
Current portion of long-term debt	10,716			15,764
Accrued interest payable	506			76
Total current liabilities	306,113			243,596
DEFERRED INCOME TAXES	26,473			4,881
LONG-TERM DEBT	95,000			57,178
OTHER LONG-TERM LIABILITIES	126			125
Total liabilities	427,712			305,780
COMMITMENTS AND CONTINGENCIES (Note 9)
SHAREHOLDERS’ EQUITY:
Common stock, $0.001 par value, 200,000,000 shares authorized, 83,543,646 and 83,039,854 shares issued, respectively	84			83
Additional paid-in capital	609,717			607,466
Accumulated deficit	(118,498		)	(194,297		)
Total shareholders’ equity	491,303			413,252
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	919,015		$	719,032

See accompanying notes to condensed consolidated financial statements

PROPETRO HOLDING CORP. AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)

(Unaudited)



	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
REVENUE - Service revenue	$	459,888		$	213,492		$	845,107		$	385,423
COSTS AND EXPENSES
Cost of services (exclusive of depreciation and amortization)	351,888			176,777			650,010			326,342
General and administrative (inclusive of stock-based compensation)	14,178			7,916			26,122			27,776
Depreciation and amortization	21,276			12,706			40,211			23,857
Loss on disposal of assets	18,990			9,787			26,655			20,229
Total costs and expenses	406,332			207,186			742,998			398,204
OPERATING INCOME (LOSS)	53,556			6,306			102,109			(12,781		)
OTHER INCOME (EXPENSE):
Interest expense	(2,231		)	(650		)	(3,492		)	(5,825		)
Other income (expense)	(182		)	(627		)	(412		)	(602		)
Total other income (expense)	(2,413		)	(1,277		)	(3,904		)	(6,427		)
INCOME (LOSS) BEFORE INCOME TAXES	51,143			5,029			98,205			(19,208		)
INCOME TAX EXPENSE	(12,052		)	(108		)	(22,406		)	(223		)
NET INCOME (LOSS)	$	39,091		$	4,921		$	75,799		$	(19,431	)
NET INCOME (LOSS) PER COMMON SHARE:
Basic	$	0.47		$	0.06		$	0.91		$	(0.28	)
Diluted	$	0.45		$	0.06		$	0.87		$	(0.28	)
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic	83,447			83,040			83,265			69,593
Diluted	86,878			86,279			87,124			69,593

See accompanying notes to condensed consolidated financial statements

PROPETRO HOLDING CORP. AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENT OF SHAREHOLDERS' EQUITY

(In thousands)

(Unaudited)



	Common Stock
	Shares	Amount		Additional Paid-In Capital		Accumulated Deficit			Total
BALANCE - January 1, 2018	83,040	$	83	$	607,466	$	(194,297	)	$	413,252
Stock-based compensation cost	—	—		2,201		—			2,201
Issuance of equity awards, net	504	1		50		—			51
Net income	—	—		—		75,799			75,799
BALANCE - June 30, 2018	83,544	$	84	$	609,717	$	(118,498	)	$	491,303

See accompanying notes to condensed consolidated financial statements

PROPETRO HOLDING CORP. AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)



	Six Months Ended June 30,
	2018			2017
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	75,799		$	(19,431	)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization	40,211			23,857
Deferred income tax expense	21,592			111
Amortization of deferred revenue rebate	615			923
Amortization of deferred debt issuance costs	191			3,240
Stock-based compensation	2,201			7,978
Loss on disposal of fixed assets	27,804			20,229
Gain on interest rate swap	—			(199		)
Changes in operating assets and liabilities:
Accounts receivable	(116,843		)	(32,641		)
Other current assets	(383		)	3,423
Inventories	(1,559		)	(107		)
Prepaid expenses	1,708			(2,321		)
Accounts payable	59,109			(2,812		)
Accrued and other current liabilities	12,941			(2,605		)
Accrued interest	1,056			(108		)
Net cash provided by (used in) operating activities	124,442			(463		)
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(152,191		)	(112,630		)
Proceeds from sale of assets	2,282			1,229
Net cash used in investing activities	(149,909		)	(111,401		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	57,378			232
Repayments of borrowings	(25,230		)	(163,128		)
Repayments of insurance financing	(3,218		)	(2,476		)
Payment of debt issuance costs	(360		)	(1,653		)
Proceeds from exercise of equity awards	51			—
Proceeds from IPO	—			185,500
Payment of IPO costs	—			(15,099		)
Net cash provided by financing activities	28,621			3,376
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	3,154			(108,488		)
CASH AND CASH EQUIVALENTS - Beginning of period	23,949			133,596
CASH AND CASH EQUIVALENTS - End of period	$	27,103		$	25,108

See accompanying notes to condensed consolidated financial statements

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 - Basis of Presentation

The accompanying condensed consolidated financial statements of ProPetro Holding Corp. and its subsidiary (the "Company," "we," "us" or "our") have been prepared in accordance with the requirements of the U.S. Securities and Exchange Commission ("SEC") for interim financial information and do not include all of the information and footnotes required by accounting principles generally accepted in the United States of America ("GAAP") for annual financial statements. Those adjustments (which consisted of normal recurring accruals) that are, in the opinion of management, necessary for a fair presentation of the results of the interim periods have been made. Results of operations for such interim periods are not necessarily indicative of the results of operations for a full year due to changes in market conditions and other factors. The condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto for the year ended December 31, 2017 included in our Form 10-K filed with the SEC ("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, separated by reportable segment and all other, from which the Company generates its revenue.

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

Hydraulic fracturing is a well-stimulation technique intended to optimize hydrocarbon flow paths during the completion phase of shale wellbores. The process involves the injection of water, sand and chemicals under high pressure into shale formations. Hydraulic fracturing contracts with our customer have one performance obligation, which is the contracted total stages, satisfied over time. We recognize revenue over time using a progress output method, unit-of-work performed method, which is based on the agreed fixed transaction price and actual stages completed. We believe that recognizing revenue based on actual stages completed faithfully depicts how our hydraulic fracturing services are transferred to our customers over time.

Acidizing, which is part of our hydraulic fracturing operating segment, involves a well-stimulation technique where acid is injected under pressure into formations to form or expand fissures. Acidizing provides downhole solutions, and contracts with customers have one performance obligation, which is 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 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. Cementing involves well bonding solutions, and contracts with customers have one performance obligation, which is satisfied at a point-in-time upon completion of the contracted service when control is transferred to the customer. Jobs for these services are typically short term in nature, with most jobs completed in less than a day. We recognize cementing revenue at a point-in-time, upon completion of the performance obligation. The transaction price for each performance obligation for all our pressure pumping services are fixed per our contract with customer.

All Other— All other services consist of our surface air drilling, drilling, coil tubing and flowback, which are all downhole well simulation and completion/remedial services. The performance obligation for each of the services has a fixed transaction price which is satisfied at a point-in-time upon completion of the service when control is transferred to the customer. Accordingly, we recognize revenue at a point-in-time, upon completion of the service and transfer of control to the customer.

Accounts Receivable

Accounts receivables are stated at the amount billed and billable to customers. At June 30, 2018 and December 31, 2017, accrued revenue (unbilled receivable) included as part of our accounts receivable was $43.4 million and $24.8 million, respectively. At June 30, 2018, the transaction price allocated to the remaining performance obligation for our partially completed hydraulic fracturing operations was $36.9 million, which is expected to be completed and recognized in the two months following the current period balance sheet date, in our pressure pumping reportable segment.

-5-

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 - Basis of Presentation (Continued)

Initial Public Offering

On March 22, 2017, we consummated our initial public offering ("IPO"), in which 25,000,000 shares of our common stock, par value $0.001 per share, were sold at a public offering price of $14.00 per share, with 13,250,000 shares issued and sold by the Company and 11,750,000 shares sold by selling stockholders. We received net proceeds of approximately $170.1 million after deducting $10.9 million of underwriting discounts and commissions, and $4.5 million of other offering expenses. At closing, we used the proceeds (i) to repay $71.8 million in outstanding borrowings under our term loan, (ii) $86.8 million to fund the purchase of additional hydraulic fracturing units and other equipment, and (iii) the remaining for general corporate purposes. In connection with the IPO, we executed a stock split, such that each holder of common stock of the Company received 1.45 shares of common stock for every one share of previous common stock, and all 16,999,990 shares of our previously outstanding Series A preferred stock converted to common stock on a 1:1 basis.

Note 2 - Recently Issued Accounting Standards

In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2014-09, Revenue from Contracts with Customers (Topic 606). ASU No. 2014-09 requires entities to recognize revenue to depict transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU No. 2014-09 requires entities to disclose both qualitative and quantitative information that enables users of the consolidated financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers, including disclosure of significant judgments affecting the recognition of revenue. ASU No. 2014-09 was effective for annual periods beginning after December 15, 2017, using either the full retrospective or modified retrospective method. We adopted ASU No. 2014-09 effective January 1, 2018, using the modified retrospective method. The adoption of this guidance had a nil impact on our prior period consolidated financial statements. This is because prior to the effective date of the new revenue guidance, substantially all of our performance obligations per our contracts with customers, except for hydraulic fracturing, were completed at a point-in-time and revenue recognized when control was transferred to the customers, which is consistent with ASU No. 2014-09. Our hydraulic fracturing segment performance obligation is satisfied over time. Prior to the effective date of the new revenue standards, our hydraulic fracturing segment revenue was recognized based on actual stages completed, i.e. using the output method, which faithfully depicts how our services are transferred over time to our customers, and is consistent with the requirements of the new guidance, ASU No. 2014-09. Accordingly, no adjustments to our consolidated financial statements were required, other than the additional disclosures included as part of Note 1 in these condensed consolidated financial statements.

In February 2016, the FASB issued ASU No. 2016-02, Leases. This ASU introduces a lessee model that brings most leases on the balance sheet. This new standard increases transparency and comparability by recognizing a lessee’s rights and obligations resulting from leases by recording them on the balance sheet as Right of Use ("ROU") Assets and Lease Liabilities. Leases will be classified as either finance or operating, which will impact the pattern of expense recognition on the income statement. However, the ASU eliminates the use of bright-line tests in determining lease classification as required in the current guidance. The ASU also requires additional qualitative and quantitative disclosures to better enable users of financial statements to assess the amount, timing, and uncertainty of cash flows arising from leases. This ASU is effective for annual reporting periods beginning after December 15, 2018, using a modified retrospective approach. Early adoption is permitted. We are in the process of finalizing the impact this guidance will have on our consolidated financial statements. Per our analysis thus far, we do not expect this new guidance to have a material impact on our consolidated financial statements. However, we will record the balance sheet impact associated with ROU assets and lease liabilities on our leases. Additionally, we intend to adopt the modified retrospective approach with an election to implement the guidance only in our 2019 consolidated financial statements, which is the year it becomes effective for us.

In January 2017, the FASB issued ASU No. 2017-04, Simplifying the Test for Goodwill Impairment, which removes the requirement to compare the implied fair value of goodwill with its carrying amount as part of step two of the goodwill impairment test. As a result, under this ASU, an entity would recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. This pronouncement is effective for impairment tests in fiscal years beginning after December 15, 2019, on a prospective basis. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. We believe that the adoption of this guidance will not materially affect our consolidated financial statements.

-6-

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 3 - Fair Value Measurements

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

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

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

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

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

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

Assets and Liabilities Measured at Fair Value on a Recurring Basis

Our financial instruments include cash and cash equivalents, accounts receivable and accounts payable. The estimated fair value of our financial instruments — cash and cash equivalents, accounts receivable and accounts payable at June 30, 2018 and December 31, 2017 approximates their carrying value as reflected in our condensed consolidated balance sheets due to their short-term nature.

Assets Measured at Fair Value on a Nonrecurring Basis

Assets measured at fair value on a nonrecurring basis at June 30, 2018 and December 31, 2017, respectively, are set forth below:

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)

($ in thousands)

June 30, 2018:

Property and equipment, net

—

Goodwill

—

December 31, 2017:

Property and equipment, net

—

Goodwill

—

No impairment of property and equipment was recorded during the six months ended June 30, 2018 and 2017.

We generally apply fair value techniques to our reporting units on a nonrecurring basis associated with valuing potential impairment loss related to goodwill. Our estimate of the reporting unit fair value is based on a combination of income and market approaches, Level 1 and 3, respectively, in the fair value hierarchy. The income approach involves the use of a discounted cash flow method, with the cash flow projections discounted at an appropriate discount rate.

-7-

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 3 - Fair Value Measurement (Continued)

The market approach involves the use of comparable public companies market multiples in estimating the fair value. Significant assumptions include projected revenue growth, capital expenditures, utilization, gross margins, discount rates, terminal growth rates, and weight allocation between income and market approaches. If the reporting unit's carrying amount exceeds its fair value, we consider goodwill impaired, and the impairment loss is calculated and recorded. There were no additions to, or disposal of, goodwill during the six months ended June 30, 2018 and 2017. At December 31, 2017, we determined our goodwill balance not to be impaired as per our annual impairment test.

Note 4 - Long-Term Debt

ABL Credit Facility

On March 22, 2017, we entered into a new revolving credit facility with a $150.0 million borrowing capacity ("ABL Credit Facility"). Borrowings under the ABL Credit Facility accrue interest based on a three-tier pricing grid tied to availability, and we may elect for loans to be based on either LIBOR or base rate, plus the applicable margin, which ranges from 1.75% to 2.25% for LIBOR loans and 0.75% to 1.25% for base rate loans, with no LIBOR floor. Borrowings under the ABL Credit Facility are secured by a first priority lien and security interest in substantially all assets of the Company. The ABL Credit Facility has a tenor of 5 years and a borrowing base of 85% of eligible accounts receivable less customary reserves. 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. In addition, the ABL Credit Facility includes a Springing Fixed Charge Coverage Ratio of 1.0x when excess availability is less than the greater of (i) 10% of the lesser of the facility size and the Borrowing Base and (ii) $12.0 million. The ABL has a commitment fee of 0.375%, which reduces to 0.25% if utilization is greater than 50% of the borrowing base.

On February 22, 2018, we entered into an amendment with our lenders to increase the capacity of the ABL Credit Facility. The amendment increased total capacity under the facility from $150.0 million to $200.0 million. The amended ABL Credit Facility includes a Springing Fixed Charge Coverage Ratio of 1.0x when excess availability is less than the greater of (i) 10% of the lesser of the facility size and the Borrowing Base and (ii) $15 million.

Total debt consisted of the following at June 30, 2018 and December 31, 2017, respectively:



($ in thousands)	2018		2017
ABL Credit Facility	$	95,000	$	55,000
Equipment financing	10,716		17,942
Total debt	105,716		72,942
Less deferred loan costs, net of amortization	—		—
Subtotal	105,716		72,942
Less current portion of long-term debt	10,716		15,764
Total long-term debt, net of deferred loan costs	$	95,000	$	57,178

The loan origination costs relating to the ABL Credit Facility are classified as an asset in the balance sheet.

Annual Maturities — Scheduled remaining annual maturities of total debt are as follows at June 30, 2018:



($ in thousands)
2018	$	10,716
2019	—
2020	—
2021	—
2022 and thereafter	95,000

Total	$	105,716

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PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 5- Reportable Segment Information

The Company has six operating segments for which discreet financial information is readily available: hydraulic fracturing (inclusive of acidizing), cementing, coil tubing, flowback, surface drilling, and drilling. These segments represent how the Chief Operating Decision Maker (CODM) evaluates performance and allocates resources. During the fourth quarter of 2017, our acidizing operation was consolidated into our hydraulic fracturing operating segment, and we no longer maintain discreet financial information for acidizing, resulting in a reduction in the number of our operating segments from seven previously reported in 2017 to six operating segments. The change in the number of our operating segments did not impact our reportable segment information reported during the three and six months ended June 30, 2018 and 2017.

In accordance with Accounting Standards Codification 280—Segment Reporting, the Company has one reportable segment (pressure pumping) comprised of the hydraulic fracturing and cementing operating segments. All other operating segments and corporate administrative expenses are included in the ‘‘all other’’ category in the table below. 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, taxes, depreciation & amortization, stock-based compensation 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.



	Three Months Ended June 30, 2018
($ in thousands)	Pressure Pumping		All Other			Total

Service revenue	$	445,805	$	14,083		$	459,888
Adjusted EBITDA	$	97,818	$	(1,850	)	$	95,968
Depreciation and amortization	$	20,042	$	1,234		$	21,276
Goodwill	$	9,425	$	—		$	9,425
Capital expenditures	$	68,106	$	2,437		$	70,543
Total assets	$	881,347	$	37,668		$	919,015

	Three Months Ended June 30, 2017
($ in thousands)	Pressure Pumping		All Other			Total
Service revenue	$	203,591	$	9,901		$	213,492
Adjusted EBITDA	$	31,362	$	(706	)	$	30,656
Depreciation and amortization	$	11,596	$	1,110		$	12,706
Goodwill	$	9,425	$	—		$	9,425
Capital expenditures	$	86,302	$	1,047		$	87,349
Total assets at December 31, 2017	$	688,279	$	30,753		$	719,032

-9-

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 5- Reportable Segment Information (Continued)



	Six Months Ended June 30, 2018
($ in thousands)	Pressure Pumping		All Other			Total

Service revenue	$	820,850	$	24,257		$	845,107
Adjusted EBITDA	$	176,881	$	(4,169	)	$	172,712
Depreciation and amortization	$	37,805	$	2,406		$	40,211
Goodwill	$	9,425	$	—		$	9,425
Capital expenditures	$	145,540	$	4,956		$	150,496
Total assets	$	881,347	$	37,668		$	919,015

	Six Months Ended June 30, 2017
($ in thousands)	Pressure Pumping		All Other			Total
Service revenue	$	367,431	$	17,992		$	385,423
Adjusted EBITDA	$	48,283	$	(1,399	)	$	46,884
Depreciation and amortization	$	21,591	$	2,266		$	23,857
Goodwill	$	9,425	$	—		$	9,425
Capital expenditures	$	141,345	$	2,466		$	143,811
Total assets at December 31, 2017	$	688,279	$	30,753		$	719,032

-10-

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 5- Reportable Segment Information (Continued)

Reconciliation of net income (loss) to adjusted EBITDA:



	Three Months Ended June 30, 2018
($ in thousands)	Pressure Pumping		All Other			Total
Net income (loss)	$	57,524	$	(18,433	)	$	39,091
Depreciation and amortization	20,042		1,234			21,276
Interest expense	—		2,231			2,231
Income tax expense	—		12,052			12,052
Loss/(gain) on disposal of assets	19,823		(833		)	18,990
Stock-based compensation	—		1,443			1,443
Other expense	—		182			182
Other general and administrative expense ⁽¹⁾	2		16			18
Deferred IPO bonus expense	427		258			685
Adjusted EBITDA	$	97,818	$	(1,850	)	$	95,968

	Three Months Ended June 30, 2017
($ in thousands)	Pressure Pumping		All Other			Total
Net income (loss)	$	9,633	$	(4,712	)	$	4,921
Depreciation and amortization	11,596		1,110			12,706
Interest expense	—		650			650
Income tax expense	—		108			108
Loss/(gain) on disposal of assets	9,681		106			9,787
Stock-based compensation	—		609			609
Other expense	—		627			627
Other general and administrative expense⁽¹⁾	—		572			572
Deferred IPO bonus expense	452		224			676
Adjusted EBITDA	$	31,362	$	(706	)	$	30,656

^{(1) Other general and administrative expense relates to legal settlement expense.}

-11-

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 5- Reportable Segment Information (Continued)



	Six Months Ended June 30, 2018
($ in thousands)	Pressure Pumping		All Other			Total
Net income (loss)	$	110,458	$	(34,659	)	$	75,799
Depreciation and amortization	37,805		2,406			40,211
Interest expense	—		3,492			3,492
Income tax expense	—		22,406			22,406
Loss/(gain) on disposal of assets	27,651		(996		)	26,655
Stock-based compensation	—		2,201			2,201
Other expense	—		412			412
Other general and administrative expense ⁽¹⁾	2		18			20
Deferred IPO bonus expense	965		551			1,516
Adjusted EBITDA	$	176,881	$	(4,169	)	$	172,712

	Six Months Ended June 30, 2017
($ in thousands)	Pressure Pumping		All Other			Total
Net income (loss)	$	1,715	$	(21,146	)	$	(19,431	)
Depreciation and amortization	21,591		2,266			23,857
Interest expense	—		5,825			5,825
Income tax expense	—		223			223
Loss/(gain) on disposal of assets	20,391		(162		)	20,229
Stock-based compensation	—		7,978			7,978
Other expense	—		602			602
Other general and administrative expense ⁽¹⁾	—		572			572
Deferred IPO bonus expense	4,586		2,443			7,029
Adjusted EBITDA	$	48,283	$	(1,399	)	$	46,884

^{(1) Other general and administrative expense relates to legal settlement expense.}

-12-

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 6 - Net Income (Loss) Per Share

Basic net income (loss) per common share is computed by dividing the net income (loss) relevant to the common stockholders by the weighted-average number of 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 stocks units outstanding during the period calculated using the treasury method and the potential dilutive effects of preferred stocks (if any) calculated using the if-converted method. The table below shows the calculations for the three and six months ended June 30, 2018 and 2017.



	Three Months Ended June 30,				Six Months Ended June 30,
(In thousands, except for per share data)	2018		2017		2018		2017
Numerator (both basic and diluted)
Net income (loss) relevant to common stockholders	$	39,091	$	4,921	$	75,799	$	(19,431	)
Denominator
Denominator for basic income (loss) per share	83,447		83,040		83,265		69,593
Dilutive effect of stock options	3,124		2,867		3,379		—
Dilutive effect of performance stock units	172		—		169		—
Dilutive effect of non-vested restricted stock	135		372		311		—
Denominator for diluted income (loss) per share	86,878		86,279		87,124		69,593
Basic income (loss) per common share	$	0.47	$	0.06	$	0.91	$	(0.28	)
Diluted income (loss) per common share	$	0.45	$	0.06	$	0.87	$	(0.28	)

As shown in the table below, the following stock options, performance stock units and non-vested restricted stocks have not been included in the calculation of diluted income (loss) per share as they will be anti-dilutive to the calculation above.



(In thousands)	Three Months Ended June 30,		Six Months Ended June 30,
	2018	2017	2018	2017
Stock options	—	793	—	4,640
Performance stock units	—	170	—	170
Non-vested restricted stock	—	319	—	692
Total	—	1,282	—	5,502

-13-

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 7 - Stock-Based Compensation

Stock Options

A summary of the stock option activity for the six months ended June 30, 2018 is presented below.



	Number of Shares		Weighted Average Exercise Price

Outstanding at January 1, 2018	4,636,353		$	5.20
Granted	—		$	—
Exercised	(3,625	)	$	14.00
Forfeited	(10,875	)	$	14.00
Expired	—		$	—
Canceled	—		$	—
Outstanding at June 30, 2018	4,621,853		$	5.17
Exercisable at June 30, 2018	4,041,277		$	3.90

The weighted average grant-date fair value of stock options granted during the six months ended June 30, 2018 and 2017 was $0 and $3.35, respectively. As of June 30, 2018, the aggregate intrinsic value for our outstanding stock options was $48.6 million, and the aggregate intrinsic value for our exercisable stock options was $47.6 million. The aggregate intrinsic value for the exercised stock options during the six months ended June 30, 2018 was $0.02 million. The remaining contractual term for the outstanding and exercisable stock options as of June 30, 2018, was 6.4 years and 6.1 years, respectively. For the six months ended June 30, 2018 and 2017, we recognized $0.3 million and $2.6 million, in stock compensation expense related to these stock option awards.

Restricted Stock Units (Non-Vested Stock) and Performance Stock Units

During the six months ended June 30, 2018, we granted a total of 319,250 restricted stock units ("RSUs") to employees, directors and executives pursuant to our Incentive Award Plan ("IAP"). Each RSU represents the right to receive one share of common stock. The fair value of the RSUs is based on the closing share price of our common stock on the date of grant. During the six months ended June 30, 2018 and 2017, the recorded stock compensation expense for all RSUs was $1.2 million and $5.3 million, respectively. As of June 30, 2018 the total unrecognized compensation expense for all RSUs was approximately $7.5 million, and is expected to be recognized over a weighted-average period of approximately 2.6 years.

The following table summarizes RSUs activity during the six months ended June 30, 2018:



	Number of Shares		Weighted Average Grant Date Fair Value
Outstanding at January 1, 2018	688,744		$	13.66
Granted	319,250		$	18.49
Vested	(500,360	)	$	13.87
Forfeited	(5,657	)	$	13.25
Expired	—		$	—
Canceled	—		$	—
Outstanding at June 30, 2018	501,977		$	16.52

-14-

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 7 - Stock-Based Compensation (Continued)

Effective April 18, 2018, our Board of Directors authorized and granted performance stock units ("PSUs") to certain key employees under the IAP. The actual number of shares that may be issued under the PSUs ranges from zero up to a maximum of twice the target number of performance stock unit awards granted to the participant, based on our total shareholder return relative to a designated peer group from January 1, 2018 through December 31, 2020. Compensation expense is recorded ratably over the corresponding requisite service period. The 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. During the six months ended June 30, 2018 and 2017, the recorded stock compensation expense for the PSUs was $0.7 million and $0.1 million, respectively.

The following table summarizes information about the PSUs that were outstanding at June 30, 2018:



Period Granted	Target Shares Outstanding at Beginning of Period	Target Shares Granted	Target Shares Vested	Target Shares Forfeited	Target Shares Outstanding at End of Period	Weighted Average Grant Date Fair Value per Share
2017	169,635	—	—	—	169,635	$	10.73
2018	—	178,975	—	—	178,975	$	27.51
Total	169,635	178,975	—	—	348,610	$	19.34

The total stock compensation expense for the six months ended June 30, 2018 and 2017 for all stock awards was $2.2 million and $8.0 million, respectively. The total unrecognized compensation expense as of June 30, 2018 is approximately $14.9 million, and is expected to be recognized over a weighted-average period of approximately 2.5 years.

-15-

PROPETRO HOLDING CORP. AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 8 - Related-Party Transactions

The Company leases its corporate offices from a related party pursuant to a five-year lease agreement with a five-year extension option requiring a base rent of $0.1 million per year. The Company also leases five properties adjacent to the corporate office from related parties with annual base rents of $0.03 million, $0.03 million, $0.1 million, $0.1 million, and $0.2 million.

For the six months ended June 30, 2018 and 2017, the Company paid approximately $0.06 million and $0.12 million, respectively, for the use of transportation services from a related party. The Company also rents equipment in Elk City, Oklahoma from a related party. For the six months ended June 30, 2018 and 2017, the Company paid $0.1 million and $0.1 million, respectively.

At June 30, 2018 and December 31, 2017, the Company had $0.03 million and $0.02 million in payables, respectively, and approximately $0 and $0 in receivables, respectively, for services provided by related parties.

All agreements pertaining to real property and equipment were entered into during periods where the Company had limited liquidity and related parties secured them on behalf of the Company. All related party transactions are immaterial and have not been separately shown on the face of the financial statements.

Note 9 - Commitments and Contingencies

Operating Lease

We have various operating leases for office space and certain property and equipment. For the six months ended June 30, 2018 and 2017, we recorded operating lease expense of $0.8 million and $0.7 million, respectively. Required remaining lease payments for each fiscal year are as follows:



($ in thousands)
2018	$	316
2019	391
2020	344
2021	344
2022 and thereafter	430
Total	$	1,825

Contingent Liabilities

We may be subject to various legal actions, claims, and liabilities arising in the ordinary course of business. In the opinion of management, the ultimate disposition of these matters will not have a materially adverse effect on our financial position, results of operations, or liquidity.

-16-

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This document contains forward-looking statements that are intended to be covered by the safe harbor provided by the Private Securities Litigation Reform Act of 1995. Forward-looking statements are predictive in nature, refer to future events or conditions, and generally not historical facts. Words such as "may," "could," "plan," "project," "budget," "predict," "pursue," "target," "seek," "objective," "believe," "expect," "anticipate," "intend," "estimate," "will," "should" and similar expressions are intended to identify forward-looking statements. These statements include, but are not limited to statements about our business strategy, industry, future profitability and future capital expenditures. Such statements are subject to risks and uncertainties, many of which are difficult to predict and generally beyond our control, that could cause actual results to differ materially from those implied or projected by the forward-looking statements. Factors that could cause our actual results to differ materially from those contemplated by such forward-looking statements include:


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


•	changes in general economic and geopolitical conditions;


•	competitive conditions in our industry;


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


•	actions taken by our customers, suppliers, competitors and third-party operators;


•	changes in the availability and cost of capital;


•	our ability to successfully implement our business plan;


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


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


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


•	changes in our tax status;


•	technological changes;


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


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


•	the effects of future litigation; and


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

Readers are cautioned not to place undue reliance on our forward-looking statements. We do not undertake to update or revise any forward-looking statements, 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.

-17-

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

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

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

Overview

We are a growth-oriented, Midland, Texas-based oilfield services company providing hydraulic fracturing and other complementary services to leading upstream oil and gas companies engaged in the exploration and production ("E&P") of North American unconventional oil and natural gas resources. Our operations are primarily focused in the Permian Basin, where we have cultivated long-standing customer relationships with some of the region's most active and well-capitalized E&P companies. The Permian Basin is widely regarded as the most prolific oil-producing area in the United States, and we believe we are currently one of the largest providers of hydraulic fracturing services in the region by hydraulic horsepower ("HHP"), with a current aggregate deployed capacity of 860,000 HHP. At June 30, 2018, our fleet, which consists of 19 hydraulic fracturing fleets, has been designed to handle the highest intensity, most complex hydraulic fracturing jobs and has remained 100% utilized since the beginning of 2017. During the quarter ended June 30, 2018, we deployed one new hydraulic fracturing fleet with 45,000 HHP. In addition, we have committed to acquire one new additional hydraulic fracturing fleet (45,000 HHP) which is expected to be delivered and put into service in the fourth quarter of 2018, bringing our aggregate capacity to 905,000 HHP or 20 fleets, by the end of 2018.

Through our pressure pumping segment (which also includes cementing operation), we primarily provide hydraulic fracturing services to E&P companies in the Permian Basin. Our modern hydraulic fracturing fleet has been designed to handle Permian Basin specific operating conditions and the region's increasingly high-intensity well completions, which are characterized by longer horizontal wellbores, more frac stages per lateral and increasing amounts of proppant per well. The majority of our fleet has been delivered in recent years, and we fully maintained our equipment through the recent industry downturn to ensure optimal performance and reliability. Additionally, substantially all of our hydraulic horsepower has been sourced from a single manufacturer, leading to a homogeneous fleet with streamlined maintenance programs and training for our personnel.

In addition to our core pressure pumping segment operations, we also offer a suite of complementary well completion and production services, including coiled tubing, flowback, drilling and surface air drilling. We believe these complementary services create operational efficiencies for our customers and allow us to capture a greater portion of their capital spending across the lifecycle of a well. Additionally, we believe that these complementary services should benefit from a continued industry recovery and that we are well positioned to continue expanding these offerings in response to our customers' service needs and spending levels.

Industry Trends and Outlook

The oil and gas industry has traditionally been volatile and is influenced by a combination of long-term, short-term and cyclical trends, including domestic and international supply and demand for oil and gas, current and expected future prices for oil and gas and the perceived stability and sustainability of those prices, and capital investments of E&P companies toward their development and production of oil and gas reserves. The oil and gas industry is also impacted by general domestic and international economic conditions, political instability in oil producing countries, government regulations (both in the United States and internationally), levels of consumer demand, adverse weather conditions, and other factors that are beyond our control. Declines and sustained weakness in crude oil prices began in the fourth quarter of 2014 and continued into February 2016, when the closing crude oil price for West Texas Intermediate (WTI) reached a low of approximately $26.19 per barrel. This decline in WTI oil prices caused our customers to reduce drilling and completion activity and curtail spending. These declines adversely affected the demand for our equipment and services and negatively impacted the prices we were able to charge our customers.

Most recently, WTI crude oil prices have averaged over $65 per barrel in June of 2018. Recent prices have resulted in a considerable increase in drilling and completion activity, and associated demand for our services. The Permian Basin, our primary area of operation, is leading the recovery with the number of active drilling rigs in the basin increasing from a low of

-18-

137 rigs in May 2016 to 474 rigs in June 2018, according to Baker Hughes. In addition to increased activity levels in the Permian Basin, several evolving industry trends, including increasingly longer horizontal wellbore laterals, a greater number of fractured stages per lateral and increasing amounts of proppant employed per well, have significantly increased demand for our hydraulic fracturing and other completion services.

With the recent shift towards more intensive horizontal drilling in the Permian Basin, operators and service providers are placing significant focus on drilling and completion efficiencies, such as multi-well pads and zipper fracturing. Multi-well pads allow for the drilling of multiple wellbores from a single topside location, reducing average drilling time. Similarly, zipper fracturing allows for the alternating completion of hydraulic fracturing stages in adjacent wells, increasing the number of stages that can be performed in a given time period. These advancements have resulted in a reduction in the number of days typically required to drill and complete a well and increased the total number of wells that can be drilled per rig, which, in turn, drives incremental demand for hydraulic fracturing services. In addition, there has been a recent shift to regional sand in the Permian Basin, which we believe will increase availability, shorten the supply chain from the mine to the well and improve operational efficiency by reducing downtime.

Rising producer activity levels, increasing basin service intensity and continued drilling and completion efficiencies have combined to drive the 100% utilization of our fleet and build a sizable backlog of addressable demand for our services. During the recent downturn, we saw our competitors defer necessary maintenance capital spending and cannibalize existing units for spare parts and idle HHP. This has resulted in tightening hydraulic fracturing supply and demand fundamentals and could drive pricing improvement for our hydraulic fracturing services. Moreover, we believe the other complementary services we provide are well-positioned to similarly benefit from a continued industry recovery.

Our competitors include many large and small oilfield services companies, including RPC, Inc., Halliburton, C&J Energy Services, Patterson-UTI Energy Inc., Keane Group, Inc., Liberty Oilfield Services, Superior Energy Services, Schlumberger, FTS International and a number of private companies. Competitive factors impacting sales of our services are price, reputation and technical expertise, service and equipment quality, and health and safety standards. Although we believe our customers consider all of these factors, we believe price is a key factor in E&P companies' criteria in choosing a service provider. While we seek to price our services competitively, we believe many of our customers elect to work with us based on our deep local roots, operational expertise, the capability of our modern fleet to handle the most complex Permian Basin well completions, and commitment to safety and reliability.

Our substantial market presence in the Permian Basin positions us well to capitalize on increasing drilling and completion activity in the region. Historically, our operational focus has been in the Permian Basin's Midland sub-basin, where our customers have primarily operated. However, with increasing levels of Delaware Basin activity, we have recently expanded our presence in the Delaware Basin in response to demand from our customers. Given our entrenched relationships with a variety of Delaware Basin operators, we believe that we are uniquely positioned to capture large addressable growth opportunity as the basin develops. Over time, we expect the Permian Basin's Midland and Delaware sub-basins to continue to command a disproportionate share of future North American E&P spending.

How We Evaluate Our Operations

Our management uses a variety of financial and operating metrics to evaluate and analyze the performance of our business, including Adjusted EBITDA and Adjusted EBITDA margin.

Adjusted EBITDA and Adjusted EBITDA margin

We view Adjusted EBITDA and Adjusted EBITDA margin as important indicators of performance. We define EBITDA as our net income (loss), 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 expenses, such as impairment charges and costs related to our initial public offering. 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, research analysts and others, 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 tax rates). Adjusted EBITDA and Adjusted EBITDA margin have limitations as analytical tools and should not be considered as an alternative to net income/(loss), operating income/(loss), cash flow from operating activities or any other measure of financial performance presented in accordance with GAAP.

-19-

Note Regarding Non-GAAP Financial Measures

Adjusted EBITDA and Adjusted EBITDA margin are not financial measures presented in accordance with GAAP. We believe that the presentation of these non-GAAP financial measures 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 is the GAAP measure most directly comparable to Adjusted EBITDA. Our non-GAAP financial measures should not be considered as alternatives to the most directly comparable GAAP financial measure. Each of these non-GAAP financial measures has important limitations as analytical tools because they exclude some, but not all, items that affect the most directly comparable GAAP financial measures. You should not consider Adjusted EBITDA or Adjusted EBITDA margin in isolation or as a substitute for an analysis of our results as reported under GAAP. Because Adjusted EBITDA and Adjusted EBITDA margin may be defined differently by other companies in our industry, our definitions of these non-GAAP financial measures may not be comparable to similarly titled measures of other companies, thereby diminishing their utility.

Reconciliation of net income (loss) to adjusted EBITDA:



	Three Months Ended June 30, 2018
($ in thousands)	Pressure Pumping		All Other			Total
Net income (loss)	$	57,524	$	(18,433	)	$	39,091
Depreciation and amortization	20,042		1,234			21,276
Interest expense	—		2,231			2,231
Income tax expense	—		12,052			12,052
Loss/(gain) on disposal of assets	19,823		(833		)	18,990
Stock-based compensation	—		1,443			1,443
Other expense	—		182			182
Other general and administrative expense ⁽¹⁾	2		16			18
Deferred IPO bonus expense	427		258			685
Adjusted EBITDA	$	97,818	$	(1,850	)	$	95,968

	Three Months Ended June 30, 2017
($ in thousands)	Pressure Pumping		All Other			Total
Net income (loss)	$	9,633	$	(4,712	)	$	4,921
Depreciation and amortization	11,596		1,110			12,706
Interest expense	—		650			650
Income tax expense	—		108			108
Loss/(gain) on disposal of assets	9,681		106			9,787
Stock-based compensation	—		609			609
Other expense	—		627			627
Other general and administrative expense⁽¹⁾	—		572			572
Deferred IPO bonus expense	452		224			676
Adjusted EBITDA	$	31,362	$	(706	)	$	30,656

^{(1) Other general and administrative expense relates to legal settlement expense.}

-20-



	Six Months Ended June 30, 2018
($ in thousands)	Pressure Pumping		All Other			Total
Net income (loss)	$	110,458	$	(34,659	)	$	75,799
Depreciation and amortization	37,805		2,406			40,211
Interest expense	—		3,492			3,492
Income tax expense	—		22,406			22,406
Loss/(gain) on disposal of assets	27,651		(996		)	26,655
Stock-based compensation	—		2,201			2,201
Other expense	—		412			412
Other general and administrative expense ⁽¹⁾	2		18			20
Deferred IPO bonus expense	965		551			1,516
Adjusted EBITDA	$	176,881	$	(4,169	)	$	172,712

	Six Months Ended June 30, 2017
($ in thousands)	Pressure Pumping		All Other			Total
Net income (loss)	$	1,715	$	(21,146	)	$	(19,431	)
Depreciation and amortization	21,591		2,266			23,857
Interest expense	—		5,825			5,825
Income tax expense	—		223			223
Loss/(gain) on disposal of assets	20,391		(162		)	20,229
Stock-based compensation	—		7,978			7,978
Other expense	—		602			602
Other general and administrative expense ⁽¹⁾	—		572			572
Deferred IPO bonus expense	4,586		2,443			7,029
Adjusted EBITDA	$	48,283	$	(1,399	)	$	46,884

^{(1) Other general and administrative expense relates to legal settlement expense.}

-21-

Results of Operations

We conduct our business through six operating segments: hydraulic fracturing (inclusive of acidizing), cementing, coil tubing, flowback, surface drilling, and drilling. For reporting purposes, the hydraulic fracturing and cementing operating segments are aggregated into our one reportable segment—pressure pumping. All other operating segments and corporate administrative expenses are included in the ‘‘all other’’category.

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



(in thousands, except for percentages)	Three Months Ended June 30,						Change
	2018			2017			Variance			%
Revenue	$	459,888		$	213,492		$	246,396		115.4	%
Cost of services ⁽¹⁾	351,888			176,777			175,111			99.1	%
General and administrative expense ⁽²⁾	14,178			7,916			6,262			79.1	%
Depreciation and amortization	21,276			12,706			8,570			67.4	%
Loss on disposal of assets	18,990			9,787			9,203			94.0	%
Interest expense	2,231			650			1,581			243.2	%
Other expense (income)	182			627			(445		)	(71.0	)%
Income tax expense	12,052			108			11,944			11,059.3	%
Net income (loss)	$	39,091		$	4,921		$	34,170		694.4	%

Adjusted EBITDA ⁽³⁾	$	95,968		$	30,656		$	65,312		213.0	%
Adjusted EBITDA Margin ⁽³⁾	20.9		%	14.4		%	6.5		%	45.1	%

Pressure pumping segment results of operations:
Revenue	$	445,805		$	203,591		$	242,214		119.0	%
Cost of services	$	341,890		$	169,275		$	172,615		102.0	%
Adjusted EBITDA	$	97,818		$	31,362		$	66,456		211.9	%
Adjusted EBITDA Margin ⁽⁴⁾	21.9		%	15.4		%	6.5		%	42.2	%

(1) Exclusive of depreciation and amortization.

(2) Inclusive of stock-based compensation.

(3) For definitions of the non-GAAP financial measures of Adjusted EBITDA and Adjusted EBITDA margin and reconciliation of Adjusted EBITDA to our most directly comparable financial measures calculated in accordance with GAAP, please read "How We Evaluate Our Operations".

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

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Three Months Ended June 30, 2018 Compared to the Three Months Ended June 30, 2017

Revenues. Revenues increased 115.4%, or $246.4 million, to $459.9 million for the three months ended June 30, 2018, as compared to $213.5 million for the three months ended June 30, 2017. The increase was primarily attributable to the increase in customer activity, fleet size and demand for our services, which has led to an increase in pricing for our hydraulic fracturing and other services. Our pressure pumping segment revenues increased 119.0%, or $242.2 million, for the three months ended June 30, 2018, as compared to the three months ended June 30, 2017. Revenues from services other than pressure pumping increased 42.2%, or $4.2 million, for the three months ended June 30, 2018 as compared to the three months ended June 30, 2017. The increase in revenues from services other than pressure pumping was primarily attributable to the increase in revenues and customer demand for our flowback, coil tubing and surface drilling services in the three months ended June 30, 2018.

Cost of Services. Cost of services increased 99.1%, or $175.1 million, to $351.9 million for the three months ended June 30, 2018, as compared to $176.8 million during the three months ended June 30, 2017. Cost of services in our pressure pumping segment increased $172.6 million for the three months ended June 30, 2018, as compared to the three months ended June 30, 2017. The increases were primarily attributable to higher activity levels, fleet size, and an increase in personnel headcount in connection with increased activity levels. As a percentage of pressure pumping segment revenues, pressure pumping cost of services decreased to 76.7% for the three months ended June 30, 2018, as compared to 83.1% for the three months ended June 30, 2017. The decrease in cost of services as a percentage of revenue for our pressure pumping segment resulted from a greater pricing power as demand for our services increased, without a corresponding increase in costs, which resulted in significantly higher realized Adjusted EBITDA margins during the three months ended June 30, 2018.

General and Administrative Expenses. General and administrative expenses increased 79.1%, or $6.3 million, to $14.2 million for the three months ended June 30, 2018, as compared to $7.9 million for the three months ended June 30, 2017. The net increase was primarily attributable to increases in payroll costs of $3.6 million, stock compensation expense of $0.8 million, property taxes of $0.9 million, insurance of $0.6 million, and $0.4 million in other remaining general and administrative expenses.

Depreciation and Amortization. Depreciation and amortization increased 67.4%, or $8.6 million, to $21.3 million for the three months ended June 30, 2018, as compared to $12.7 million for the three months ended June 30, 2017. The increase was primarily attributable to the increase in our fixed asset base as of June 30, 2018, resulting from the additional property and equipment purchased in the second half of 2017 and during the six months ended June 30, 2018. We calculate depreciation of property and equipment using the straight-line method.

Loss on Disposal of Assets. Loss on the disposal of assets increased 94.0%, or $9.2 million, to $19.0 million for the three months ended June 30, 2018, as compared to $9.8 million for the three months ended June 30, 2017. The increase is attributable to the increase in fleet size, greater service intensity of jobs completed, coupled with higher activity levels on certain of our equipment.

Interest Expense. Interest expense increased 243.2%, or $1.6 million, to $2.2 million for the three months ended June 30, 2018, as compared to $0.6 million for the three months ended June 30, 2017. The increase in interest expense was primarily attributable to an increase in our average debt balance during the three months ended June 30, 2018 compared to the three months ended June 30, 2017.

Other Expense. Other expense was $0.2 million for the three months ended June 30, 2018, as compared to $0.6 million for the three months ended June 30, 2017. The decrease is primarily attributable to the decrease in lender related expenses and unrealized loss resulting from the change in fair value of our interest rate swap.

Income Tax Expense. Total income tax expense was $12.1 million resulting in an effective tax rate of 23.6% for the three months ended June 30, 2018 as compared to $0.1 million and an effective tax rate of 2.1% for the three months ended June 30, 2017. The increase in income tax expense during the three months ended June 30, 2018 is primarily attributable to the increase in taxable income in 2018 compared to 2017.

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



(in thousands, except for percentages)	Six Months Ended June 30,						Change
	2018			2017			Variance			%
Revenue	$	845,107		$	385,423		$	459,684		119.3	%
Cost of services ⁽¹⁾	650,010			326,342			323,668			99.2	%
General and administrative expense ⁽²⁾	26,122			27,776			(1,654		)	(6.0	)%
Depreciation and amortization	40,211			23,857			16,354			68.6	%
Loss on disposal of assets	26,655			20,229			6,426			31.8	%
Interest expense	3,492			5,825			(2,333		)	(40.1	)%
Other expense (income)	412			602			(190		)	(31.6	)%
Income tax expense	22,406			223			22,183			9,947.5	%
Net income (loss)	$	75,799		$	(19,431	)	$	95,230		490.1	%

Adjusted EBITDA ⁽³⁾	$	172,712		$	46,884		$	125,828		268.4	%
Adjusted EBITDA Margin ⁽³⁾	20.4		%	12.2		%	8.2		%	67.2	%

Pressure pumping segment results of operations:
Revenue	$	820,850		$	367,431		$	453,419		123.4	%
Cost of services	$	632,360		$	312,647		$	319,713		102.3	%
Adjusted EBITDA	$	176,881		$	48,283		$	128,598		266.3	%
Adjusted EBITDA Margin ⁽⁴⁾	21.5		%	13.1		%	8.4		%	64.1	%

Six Months Ended June 30, 2018 Compared to the Six Months Ended June 30, 2017

Revenues. Revenues increased 119.3%, or $459.7 million, to $845.1 million for the six months ended June 30, 2018, as compared to $385.4 million for the six months ended June 30, 2017. The increase was primarily attributable to the increase in customer activity, fleet size and demand for our services, which has led to an increase in pricing for our hydraulic fracturing and other services. Our pressure pumping segment revenues increased 123.4%, or $453.4 million, for the six months ended June 30, 2018, as compared to the six months ended June 30, 2017. Revenues from services other than pressure pumping increased 34.8%, or $6.3 million, for the six months ended June 30, 2018 as compared to the six months ended June 30, 2017. The increase in revenues from services other than pressure pumping was primarily attributable to the increase in revenues and customer demand for our flowback, coil tubing and surface drilling services in the six months ended June 30, 2018.

Cost of Services. Cost of services increased 99.2%, or $323.7 million, to $650.0 million for the six months ended June 30, 2018, as compared to $326.3 million during the six months ended June 30, 2017. Cost of services in our pressure pumping segment increased $319.7 million for the six months ended June 30, 2018, as compared to the six months ended June 30, 2017. The increases were primarily attributable to higher activity levels, fleet size, and an increase in personnel headcount following the increased activity levels. As a percentage of pressure pumping segment revenues, pressure pumping

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cost of services decreased to 77.0% for the six months ended June 30, 2018, as compared to 85.1% for the six months ended June 30, 2017. The decrease in cost of services as a percentage of revenue for the pressure pumping segment resulted from a greater pricing power as demand for our services increased, without a corresponding increase in costs, which resulted in significantly higher realized Adjusted EBITDA margins during the six months ended June 30, 2018.

General and Administrative Expenses. General and administrative expenses decreased 6.0%, or $1.7 million, to $26.1 million for the six months ended June 30, 2018, as compared to $27.8 million for the six months ended June 30, 2017. The net decrease was primarily attributable to decreases in stock compensation expense of $5.8 million, deferred IPO bonus of $5.5 million, nonrecurring legal settlement of $0.6 million, and partially offset by increases in insurance of $1.1 million, legal and professional fees of $0.8 million, payroll cost of $5.1 million, property taxes and other related taxes of $1.8 million, and net aggregate increase in other remaining general and administrative expenses of $1.4 million.

Depreciation and Amortization. Depreciation and amortization increased 68.6%, or $16.4 million, to $40.2 million for the six months ended June 30, 2018, as compared to $23.9 million for the six months ended June 30, 2017. The increase was primarily attributable to the increase in our fixed asset base as of June 30, 2018, resulting from the additional property and equipment purchased in the second half of 2017 and during the six months ended June 30, 2018. We calculate depreciation of property and equipment using the straight-line method.

Loss on Disposal of Assets. Loss on the disposal of assets increased 31.8%, or $6.4 million, to $26.7 million for the six months ended June 30, 2018, as compared to $20.2 million for the six months ended June 30, 2017. The increase is attributable to the increase in fleet size, greater service intensity of jobs completed, and higher activity levels on certain of our equipment.

Interest Expense. Interest expense decreased 40.1%, or $2.3 million, to $3.5 million for the six months ended June 30, 2018, as compared to $5.8 million for the six months ended June 30, 2017. The decrease in interest expense was primarily attributable to a reduction in our average debt balance during the six months ended June 30, 2018 compared to the six months ended June 30, 2017.

Other Expense. Other expense was $0.4 million for the six months ended June 30, 2018, as compared to $0.6 million for the six months ended June 30, 2017. The decrease is primarily attributable to the decreases in nonrecurring listing expenses, lender related expenses and unrealized loss resulting from the change in fair value of our interest rate swap.

Income Tax Expense. Total income tax expense was $22.4 million resulting in an effective tax rate of 22.8% for the six months ended June 30, 2018 as compared to $0.2 million and an effective tax rate of 1.2% for the six months ended June 30, 2017. The increase in income tax expense during the six months ended June 30, 2018 is primarily attributable to the increase in taxable income in 2018 compared to 2017.

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Liquidity and Capital Resources

On March 22, 2017, we completed our IPO of 13,250,000 shares of common stock at $14.00 per share, from which we received net proceeds of $170.1 million which we used (i) to repay the remaining balance on our term loan, (ii) to acquire additional hydraulic fracturing fleets and (iii) for general corporate purposes.

As of June 30, 2018, our cash and cash equivalents were $27.1 million, as compared to $23.9 million at December 31, 2017. Our liquidity is currently provided by (i) existing cash balances, (ii) operating cash flows and (iii) borrowings under our ABL Credit Facility. Our primary uses of cash will be to fund our operations, support growth opportunities and satisfy debt payments.

There can be no assurance that operations and other capital resources will provide cash in sufficient amounts to maintain planned or future levels of capital expenditures. Future cash flows are subject to a number of variables, and are highly dependent on the drilling, completion, and production activity by our customers, which in turn is highly dependent on oil and 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 obligations.

Cash and Cash Flows

The following table sets forth the historical cash flows for the six months ended June 30, 2018 and 2017 :



	Six Months Ended June 30,
($ in thousands)	2018			2017
Net cash provided by (used in):
Operating activities	$	124,442		$	(463	)
Investing activities	$	(149,909	)	$	(111,401	)
Financing activities	$	28,621		$	3,376

Operating Activities

Net cash provided by operating activities was $124.4 million for the six months ended June 30, 2018, compared to net cash used in operating activities of $0.5 million for the six months ended June 30, 2017. The net increase of $124.9 million was primarily due to increases in revenue and net income in the period, offset by our working capital needs resulting from higher fleet size and expanding activity levels.

Investing Activities

Net cash used in investing activities increased to $149.9 million for the six months ended June 30, 2018, from $111.4 million for the six months ended June 30, 2017. The increase was primarily attributable to the additional equipment purchased during the period, and an increase in maintenance capital expenditures during the six months ended June 30, 2018 compared to the six months ended June 30, 2017.

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Financing Activities

Net cash provided by financing activities was $28.6 million for the six months ended June 30, 2018, and $3.4 million for the six months ended June 30, 2017. The net increase in cash provided by financing activities for the six months ended June 30, 2018 was primarily due to our borrowings under the ABL Credit Facility and equipment financing, totaling $57.4 million, partially offset by repayment of borrowings of $25.2 million, repayment of insurance financing of $3.2 million, and debt issuance cost of $0.4 million, during the six months ended June 30, 2018, compared to net cash used of $163.1 million for repayment of borrowings, repayment of insurance financing of $2.5 million, payment of debt issuance cost of $1.7 million, IPO costs of $15.1 million, and offset by proceeds from borrowings of $0.2 million and IPO proceeds of $185.5 million during the six months ended June 30, 2017.

Off-Balance Sheet Arrangements

We had no off-balance sheet arrangements as of June 30, 2018.

Critical Accounting Policies and Estimates

There have been no material changes during the six months ended June 30, 2018 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 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.

Volatility of Oil and Natural Gas Prices and its Impact on Operations and Financial Condition

Our revenue, profitability and cash flows are highly dependent upon prevailing prices for West Texas Intermediate (WTI) oil and natural gas and expectations about future prices. For many years, WTI oil and natural gas prices and markets have been extremely volatile. Prices are affected by many factors beyond our control. WTI oil prices declined significantly close to the end of the second half of 2014. The closing price of WTI oil, which was as high as $105.68 per barrel during the third quarter of 2014, averaged $48.69 during 2015 and reached a twelve-year low of $26.19 in February 2016. However, beginning in the third quarter of 2016, WTI oil prices started recovering, and reaching an average of over $65 per barrel in June of 2018. As a result of the recent recovery in WTI oil prices, our industry has experienced a significant increase in both drilling and pressure pumping activity levels. Looking forward, assuming commodity prices remain at or above recent levels, we believe U.S. rig counts will continue to increase. We expect WTI oil and natural gas prices to continue to be volatile and to affect our financial condition, operations and ability to access sources of capital. Higher WTI oil and natural gas prices do not necessarily result in increased activity because demand for our services is generally driven by our customers’ expectations of future oil and natural gas prices.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As of June 30, 2018, 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.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

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

As required by Rule 13a-15(b) under the Exchange Act, we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this Quarterly Report. Based upon that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective at the reasonable assurance level as of June 30, 2018.

Changes in Internal Control over Financial Reporting

No changes in our system of internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) occurred during the quarterly period ended June 30, 2018 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II – OTHER INFORMATION

ITEM 1. Legal Proceedings

From time to time, we may be subject to various legal proceedings and claims incidental to or arising in the ordinary course of our business. We are not currently party to any legal proceedings that we believe would have a material adverse effect on our financial position or results of operations, and we are not aware of any material legal proceedings contemplated by governmental authorities.

ITEM 1A. Risk Factors

There have been no material changes to our principal risks that we believe are material to our business, results of operations, and financial condition from the risk factors previously disclosed in our final Form 10-K, which is accessible on the SEC’s website at www.sec.gov.

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

None.

ITEM 3. Defaults Upon Senior Securities

None.

ITEM 4. Mine Safety Disclosures

Not applicable.

ITEM 5. Other Information

None.

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ITEM 6. Exhibits

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



3.1		Certificate of Incorporation of ProPetro Holding Corp., as amended March 16, 2017 (incorporated by reference to Exhibit 3.1 to the Company's Quarterly Report on Form 10-Q for the quarter ended March 31, 2017).
3.2		Bylaws of ProPetro Holding Corp. (incorporated by reference to Exhibit 3.3 to the Company’s Registration Statement on Form S-1, dated March 10, 2017 (Registration No. 333-215940)).
31.1		Certification of Chief Executive Officer pursuant to Rule 13a-14(a) and 15d-14(a) as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2		Certification of Chief Financial Officer pursuant to Rule 13a-14(a) and 15d-14(a) as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1		Certification of Chief Executive Officer pursuant to 18 U.S.C. §1350 as adopted by Section 906 of the Sarbanes-Oxley Act of 2002.
32.2		Certification of Chief Financial Officer pursuant to 18 U.S.C. §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



+	Indicates management contracts or compensatory plans or arrangements.

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SIGNATURES

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



SIGNATURES

Date:	August 9, 2018	By:	/s/ Dale Redman
			Dale Redman
			Chief Executive Officer and Director
			(Principal Executive Officer)

		By:	/s/ Jeffrey Smith
			Jeffrey Smith
			Chief Financial Officer
			(Principal Financial Officer)

		By:	/s/ Ian Denholm
			Ian Denholm
			Chief Accounting Officer
			(Principal Accounting Officer)

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