PUMP 10-Q Quarterly Report Sept. 30, 2017 | Alphaminr
ProPetro Holding Corp.
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PUMP 10-Q Quarter ended Sept. 30, 2017

Balance Sheet
Cash Flow
Income Statement
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10-Q 1 a10q9302017.htm 10-Q Document


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 September 30, 2017
or
¨
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.
Large accelerated filer
¨
Accelerated filer
¨
Non-accelerated filer
ý (Do not check if a smaller reporting company)
Smaller reporting company
¨
Emerging growth company
ý
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 October 31, 2017 , was 83,039,854


PROPETRO HOLDING CORP. AND SUBSIDIARY
TABLE OF CONTENTS
Page

- i -

PART I – FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
PROPETRO HOLDING CORP. AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except share data)
(Unaudited)
September 30, 2017
December 31, 2016
ASSETS
CURRENT ASSETS:
Cash and cash equivalents
$
51,008

$
133,596

Accounts receivable - net of allowance for doubtful accounts of $335 and $552, respectively
160,047

115,179

Inventories
9,148

4,713

Prepaid expenses
5,543

4,608

Other current assets
975

6,684

Total current assets
226,721

264,780

PROPERTY AND EQUIPMENT - Net of accumulated depreciation
399,268

263,862

OTHER NONCURRENT ASSETS:
Goodwill
9,425

9,425

Intangible assets - net of amortization
373

589

Deferred revenue rebate - net of amortization
1,077

2,462

Other noncurrent assets
1,727

304

Total other noncurrent assets
12,602

12,780

TOTAL ASSETS
$
638,591

$
541,422

LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable
$
181,660

$
129,093

Accrued liabilities
11,074

13,619

Current portion of long-term debt
7,441

16,920

Accrued interest payable
86

109

Total current liabilities
200,261

159,741

DEFERRED INCOME TAXES
1,315

1,148

LONG-TERM DEBT
34,476

159,407

OTHER LONG-TERM LIABILITIES
124

117

Total liabilities
236,176

320,413

COMMITMENTS AND CONTINGENCIES (Note 9)




SHAREHOLDERS’ EQUITY:
Preferred stock, $0.001 par value, 30,000,000 shares authorized, 0 and 16,999,990 shares issued, respectively
—

17

Preferred stock, additional paid-in capital
—

162,494

Common stock, $0.001 par value, 200,000,000 shares authorized, 83,039,854 and 52,627,652 shares issued, respectively
83

53

Additional paid-in capital
606,707

265,355

Accumulated deficit
(204,375
)
(206,910
)
Total shareholders’ equity
402,415

221,009

TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY
$
638,591

$
541,422


See accompanying notes to condensed consolidated financial statements
1

PROPETRO HOLDING CORP. AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except per share data)
(Unaudited)
Three Months Ended September 30,
Nine Months Ended September 30,
2017
2016
2017
2016
REVENUE - Service revenue
$
282,730

$
116,904

$
668,153

$
272,999

COSTS AND EXPENSES
Cost of services (exclusive of depreciation and amortization)
225,433

110,223

551,775

255,362

General and administrative (inclusive of stock-based compensation)
11,106

5,856

38,881

17,197

Depreciation and amortization
14,745

10,790

38,602

32,669

Loss on disposal of assets
8,742

5,923

28,971

12,859

Total costs and expenses
260,026

132,792

658,229

318,087

OPERATING INCOME (LOSS)
22,704

(15,888
)
9,924

(45,088
)
OTHER INCOME (EXPENSE):


Interest expense
(644
)
(4,550
)
(6,469
)
(15,942
)
Gain on extinguishment of debt
—

—

—

6,975

Other expense
(191
)
(106
)
(792
)
(419
)
Total other income (expense)
(835
)
(4,656
)
(7,261
)
(9,386
)
INCOME (LOSS) BEFORE INCOME TAXES
21,869

(20,544
)
2,663

(54,474
)
INCOME TAX (EXPENSE)/BENEFIT
96

6,946

(128
)
18,644

NET INCOME (LOSS)
$
21,965

$
(13,598
)
$
2,535

$
(35,830
)
NET INCOME (LOSS) PER COMMON SHARE:
Basic
$
0.26

$
(0.26
)
$
0.03

$
(0.84
)
Diluted
$
0.25

$
(0.26
)
$
0.03

$
(0.84
)
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic
83,040

52,975

74,124

42,526

Diluted
86,264

52,975

77,118

42,526



See accompanying notes to condensed consolidated financial statements
2

PROPETRO HOLDING CORP. AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN SHAREHOLDERS' EQUITY
(In thousands)
(Unaudited)

Preferred Stock
Common Stock
Shares
Amount
Preferred Additional Paid-In Capital
Shares
Amount
Additional Paid-In Capital
Accumulated Deficit
Total
BALANCE - January 1, 2017
17,000

$
17

$
162,494

52,628

$
53

$
265,355

$
(206,910
)
$
221,009

Stock-based compensation cost
—

—

—

—

—

8,730

—

8,730

Initial Public Offering net of costs
—

—

—

13,250

13

170,128

—

170,141

Conversion of preferred stock to common at Initial Public Offering
(17,000
)
(17
)
(162,494
)
17,000

17

162,494

—

—

Exercise of stock options—net
—

—

—

162

—

—

—

—

Net income
—

—

—

—

—

—

2,535

2,535

BALANCE - September 30, 2017
—

$
—

$
—

83,040

$
83

$
606,707

$
(204,375
)
$
402,415



See accompanying notes to condensed consolidated financial statements
3

PROPETRO HOLDING CORP. AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
(Unaudited)
Nine Months Ended September 30,
2017
2016
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)
$
2,535

$
(35,830
)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization
38,602

32,669

Gain on extinguishment
—

(6,975
)
Deferred income tax expense (benefit)
166

(18,644
)
Amortization of deferred revenue rebate
1,385

1,385

Amortization of deferred debt issuance costs
3,322

1,806

Stock-based compensation
8,730

1,130

Loss on disposal of assets
28,971

12,859

Gain on interest rate swap
(226
)
(54
)
Changes in operating assets and liabilities:
Accounts receivable
(44,868
)
3,255

Other current assets
3,271

(4
)
Inventories
(4,435
)
1,579

Prepaid expenses
(910
)
2,845

Accounts payable
41,564

(2,294
)
Accrued liabilities
589

620

Accrued interest
(23
)
1

Net cash provided by (used in) operating activities
78,673

(5,652
)
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures
(193,820
)
(18,631
)
Proceeds from sale of assets
4,237

475

Net cash used in investing activities
(189,583
)
(18,156
)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings
27,112

—

Repayments of borrowings
(164,638
)
(42,166
)
Repayments of insurance financing
(2,900
)
(2,833
)
Debt extinguishment cost
—

(525
)
Payment of debt issuance costs
(1,653
)
(115
)
Equity capitalization
—

40,425

Proceeds from IPO
185,500

—

Payment of IPO costs
(15,099
)
—

Net cash provided by (used in) financing activities
28,322

(5,214
)
NET DECREASE IN CASH AND CASH EQUIVALENTS
(82,588
)
(29,022
)
CASH AND CASH EQUIVALENTS - Beginning of period
133,596

34,310

CASH AND CASH EQUIVALENTS - End of period
$
51,008

$
5,288



See accompanying notes to condensed consolidated financial statements
4

PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(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, 2016 included in the final prospectus of the Company filed with the SEC pursuant to rule 424(b) under the Securities Act of 1933 on March 20, 2017 ("Prospectus").

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 existing 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. Upon closing of the IPO, we used the proceeds (i) to repay $71.8 million in outstanding borrowings under our Term Loan (as defined in Note 4), (ii) to fund the purchase of additional hydraulic fracturing fleets and ancillary equipment, and (iii) for general corporate purposes.
In connection with the IPO, the Company 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. Accordingly, any information related to, or dependent upon, the share or option counts in our comparative 2016 condensed consolidated financial statements (Unaudited) and Note 6, Net Income (Loss) per Share , Note 7, Stock-Based Compensation , and Note 10, Equity Capitalization , have been updated to reflect the effect of the stock split.

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 originally effective for annual periods beginning after December 15, 2016, using either the retrospective or cumulative effect transition method. On August 12, 2015, the FASB issued ASU No. 2015-14, which defers the effective date of the revenue standard, ASU No. 2014-09, by one year for all entities and permits early adoption on a limited basis. We have completed our preliminary evaluation of ASU No. 2014-09, and the adoption of this guidance will not materially affect our revenue recognition. However, there will be additional disclosures on our consolidated financial statements relating to the adoption of this standard.
In July 2015, the FASB issued ASU No. 2015-11, Simplifying the Measurement of Inventory, which requires entities to measure most inventory "at the lower of cost and net realizable value," thereby simplifying the current guidance under which an entity must measure inventory at the lower of cost or market. ASU No. 2015-11 does not apply to inventories that are measured by using either the last-in, first-out method or the retail inventory method. The amendments in ASU No. 2015-11 are effective for fiscal years beginning after December 15, 2016. The ASU became effective for us in 2017 and the adoption of this guidance did not materially affect our consolidated financial statements.
In February 2016, the FASB issued ASU No. 2016-02, Leases , a new standard on accounting for leases. The ASU introduces a lessee model that brings most leases on the balance sheet. The new standard also aligns many of the underlying principles of the new lessor model with those in the current accounting guidance as well as the FASB’s new revenue recognition standard. 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 disclosures along with specific quantitative disclosures to better enable users of financial statements to assess the amount, timing, and uncertainty of cash flows arising from leases.

- 5 -
PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(Unaudited)

Note 2 - Recently Issued Accounting Standards (Continued)


The new standard is effective for annual reporting periods beginning after December 15, 2018, including periods within that reporting period, using a modified retrospective approach. Early adoption is permitted. We have not completed an evaluation of the impact the pronouncement will have on our consolidated financial statements and related disclosures.
In March 2016, the FASB issued ASU No. 2016-09, Compensation- Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting, which modifies several aspects of the accounting for share-based payment transactions including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The new standard is effective for fiscal years and interim periods beginning after December 15, 2016, with early adoption permitted. The ASU became effective for us in 2017 and the adoption of this guidance did not materially affect our consolidated financial statements.
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.
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, accounts payable, and a derivative financial instrument. The estimated fair value of our financial instruments — cash and cash equivalents, accounts receivable and accounts payable at September 30, 2017 and December 31, 2016 approximates their carrying value as reflected in our condensed consolidated balance sheets due to their short-term nature. We use a derivative financial instrument, an interest rate swap, to manage interest rate risk. Our policies do not permit the use of derivative financial instruments for speculative purposes. We did not designate the interest rate swap as a hedge for accounting purposes. We record all derivatives as of the end of our reporting period in our condensed consolidated balance sheet at fair value, which is based on quoted market prices, a Level 1 input. We may be exposed to credit losses in the event of nonperformance by counterparties to the interest rate swap. The counterparty of the interest rate swap is a credible, large institution, and we do not believe there is significant or material credit risk upon settlement of the contract. The fair value of the interest rate swap liability at September 30, 2017 and December

- 6 -
PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(Unaudited)

Note 3 - Fair Value Measurement (Continued)

31, 2016 was $0.03 million and $0.3 million , respectively. Based on quoted market prices as of September 30, 2017 and 2016 , for contracts with similar terms and maturity date, as provided by the counterparty, we recorded a gain of $0.2 million and $0.1 million during the nine months ended September 30, 2017 and 2016 , respectively.
Assets Measured at Fair Value on a Nonrecurring Basis
Assets measured at fair value on a nonrecurring basis at September 30, 2017 and December 31, 2016 , respectively, are set forth below:
Estimated fair value measurements
Balance
Quoted prices in active market
(Level 1)
Significant other observable inputs (Level 2)
Significant other unobservable inputs (Level 3)
Total gains
(losses)
($ in thousands)
September 30, 2017:
Property and equipment,
net
$
—

$
—

$
—

$
—

$
—

Goodwill
$
—

$
—

$
—

$
—

$
—

December 31, 2016:
Property and equipment,
net
$
8,700

$
—

$
8,700

$
—

$
(6,305
)
Goodwill
$
9,425

$
—

$
—

$
9,425

$
(1,177
)

No impairment of property and equipment was recorded during the nine months ended September 30, 2017 and 2016 . During the fourth quarter of 2016 , the depressed cash flows and continued decline in utilization of our Permian drilling assets were indicative of potential impairment, resulting in the Company comparing the carrying value of the Permian drilling assets with its estimated fair value. We determined that the carrying value of the Permian drilling assets was greater than its estimated fair value, and as such, an impairment expense was recorded in the fourth quarter of 2016 . The non-cash asset impairment charges recorded in the fourth quarter of 2016 for Permian drilling was $6.3 million , which had a then net carrying value of $15.0 million prior to the impairment write-down.
We generally apply fair value techniques to our reporting units on a nonrecurring basis associated with valuing potential impairment loss related to goodwill. Our estimate of the reporting unit fair value is based on a combination of income and market approaches, Level 1 and 3, respectively, in the fair value hierarchy. The income approach involves the use of a discounted cash flow method, with the cash flow projections discounted at an appropriate discount rate. The market approach involves the use of comparable public companies market multiples in estimating the fair value. Significant assumptions include projected revenue growth, capital expenditures, utilization, gross margins, discount rates, terminal growth rates, and weight allocation between income and market approaches. If the reporting unit's carrying amount exceeds its fair value, we consider goodwill impaired, and the impairment loss is calculated and recorded. There were no additions to, or disposal of, goodwill during the nine months ended September 30, 2017 and 2016 . At December 31, 2016 , we estimated the fair value of the surface drilling reporting unit to be $3.8 million and its carrying value was $4.2 million . As a result of the potential impairment due to the carrying value exceeding the estimated fair value, we then further determined the implied fair value of the $1.2 million goodwill for the surface drilling reporting unit to be $0 . Accordingly, we recorded an impairment loss of $1.2 million during the fourth quarter of 2016.

- 7 -

PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(Unaudited)






Note 4 - Long-Term Debt
2013 Term Loan and Revolving Credit Facility
On September 30, 2013, we entered into a term loan in the amount of $220 million ("Term Loan") with a $40 million revolving credit line ("Revolving Credit Facility" ) . Borrowings under the Term Loan and Revolving Credit Facility accrued interest at LIBOR plus 6.25% , subject to a 1% LIBOR floor, and were secured by a first priority lien and security interest in all assets of the Company. Proceeds from the Term Loan were used to pay off 100% of our debt outstanding, including accrued interest, at September 30, 2013, with excess proceeds from the Term Loan and the Revolving Credit Facility used to fund growth and working capital needs. The Term Loan and Revolving Credit Facility were scheduled to mature on September 30, 2019 and September 30, 2018, respectively, with quarterly and monthly payments of principal and interest, respectively.
Under the Term Loan and 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 reporting, insurance, collateral maintenance, change of control, transactions with affiliates, distributions, and limitations on additional indebtedness. In addition, the Term Loan and Revolving Credit Facility included a maximum leverage ratio of 3.5 x EBITDA (earnings before interest, taxes, depreciation, and amortization) to total debt, which became effective March 31, 2014.
In 2015, given the then near-term economic uncertainty and volatility of commodity prices, we determined that we were likely to be out of compliance with the leverage ratio covenant under the Term Loan and Revolving Credit Facility at the March 31, 2016 test date. Accordingly, the Company and its equity sponsor, Energy Capital Partners ("ECP"), commenced negotiations with the lenders to amend the covenants and leverage ratio in the Term Loan and Revolving Credit Facility. The resulting amendment and waiver agreement was executed on June 8, 2016. Under the terms of the amendment, ECP infused $40 million of additional equity into the Company, $10 million of which was reserved for working capital, with up to $30 million available to repurchase debt. A minority shareholder also infused $0.425 million alongside ECP to prevent dilution. The amendment and waiver also suspended the leverage ratio test until June 30, 2017, and provided us with 30 days to deliver any past-due financial statements.
Gain on Extinguishment of Debt — in connection with the amendment to the Term Loan and Revolving Credit Facility, we initiated an auction process with the lenders to repurchase a portion of debt for a price of 80 cents , a 20% discount to par value. The auction settled on June 16, 2016 as the Company repurchased a total amount of $37.5 million of debt for $30 million plus $0.5 million in debt extinguishment auction costs, leading to a gain on extinguishment of debt of $7.0 million .
On January 13, 2017, we repaid $75 million of the outstanding balance under the Term Loan and repaid the remaining balance of $13.5 million under the Revolving Credit Facility using a portion of the proceeds from the private placement offering. On March 22, 2017, we retired the $71.8 million remaining balance of the Term Loan, along with accrued interest, using a portion of the proceeds from our IPO. Each of the Term Loan and Revolving Credit Facility were terminated in accordance with their terms upon the repayment of outstanding borrowings.
Equipment and Manufacturing Notes
On November 24, 2015, we entered into a 36 -month financing arrangement for three hydraulic fracturing fleets in the amount of $25 million , and a portion of the proceeds were used to pay off the previous manufacturer notes, with the remainder being used for additional liquidity.
On June 30, 2017, we entered into a financing arrangement for the purchase of light vehicles. As of September 30, 2017 , we purchased certain light vehicles under this financing arrangement in the amount of $2.1 million .


- 8 -
PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(Unaudited)

Note 4 - Long-Term Debt (Continued)


ABL Credit Facility
On March 22, 2017, we entered into a new revolving credit facility with a $150 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 1.0 x when excess availability is less than the greater of (i) 10% of the lesser of the facility size and the Borrowing Base and (ii) $12 million . The ABL has a commitment fee of 0.375% , which reduces to 0.25% if utilization is greater than 50% of the borrowing base.
Total debt consisted of the following at September 30, 2017 and December 31, 2016 , respectively:
($ in thousands)
2017
2016
ABL Credit Facility
$
25,000

$
—

6.25% "Term loan" due September 2019
—

146,750

Revolving Credit Facility
—

13,500

Equipment financing
16,917

19,193

Total debt
41,917

179,443

Less deferred loan costs, net of amortization
—

3,116

Subtotal
41,917

176,327

Less current portion of long-term debt
7,441

16,920

Total long-term debt, net of deferred loan costs
$
34,476

$
159,407

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 September 30, 2017 :
($ in thousands)
2017
$
1,778

2018
14,298

2019
805

2020
36

2021 and thereafter
25,000

Total
$
41,917

Note 5 - Reportable Segment Information
The Company has seven operating segments for which discreet financial information is readily available: hydraulic fracturing, cementing, acidizing, coil tubing, flowback, surface drilling, and Permian drilling. These segments represent how the Chief Operating Decision Maker (CODM) evaluates performance and allocates resources.
In accordance with Accounting Standards Codification (ASC) 280— Segment Reporting , the Company has one reportable segment (pressure pumping) comprised of the hydraulic fracturing, cementing, and acidizing 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

- 9 -
PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(Unaudited)

Note 5- Reportable Segment Information (Continued)


expense, (gain)/loss on disposal of assets, gain on extinguishment of debt 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 September 30, 2017
Nine months ended September 30, 2017
($ in thousands)
Pressure Pumping
All Other
Total
Pressure Pumping
All Other
Total
Service revenue
$
271,924

$
10,806

$
282,730

$
639,355

$
28,798

$
668,153

Adjusted EBITDA
$
50,013

$
(2,245
)
$
47,768

$
98,296

$
(3,641
)
$
94,655

Depreciation and amortization
$
13,637

$
1,108

$
14,745

$
35,228

$
3,374

$
38,602

Goodwill
$
9,425

$
—

$
9,425

$
9,425

$
—

$
9,425

Capital expenditures
$
61,752

$
765

$
62,517

$
203,097

$
3,231

$
206,328

Total assets
$
604,769

$
33,822

$
638,591

$
604,769

$
33,822

$
638,591

Three months ended September 30, 2016
Nine months ended September 30, 2016
Pressure Pumping

All Other

Total
Pressure Pumping

All Other

Total
Service revenue
$
109,697

$
7,207

$
116,904

$
251,410

$
21,589

$
272,999

Adjusted EBITDA
$
2,951

$
(1,616
)
$
1,335

$
6,500

$
(4,930
)
$
1,570

Depreciation and amortization
$
9,274

$
1,516

$
10,790

$
27,905

$
4,764

$
32,669

Goodwill
$
9,425

$
1,177

$
10,602

$
9,425

$
1,177

$
10,602

Capital expenditures
$
11,641

$
202

$
11,843

$
21,582

$
312

$
21,894

Total assets at December 31, 2016
$
501,906

$
39,516

$
541,422

$
501,906

$
39,516

$
541,422


Reconciliation of net income (loss) to adjusted EBITDA:
Three months ended September 30, 2017
Nine months ended September 30, 2017
($ in thousands)
Pressure Pumping
All Other
Total
Pressure Pumping
All Other
Total
Net income (loss)
$
28,372

$
(6,407
)
$
21,965

$
30,087

$
(27,552
)
$
2,535

Depreciation and amortization
13,637

1,108

14,745

35,228

3,374

38,602

Interest expense
—

644

644

—

6,469

6,469

Income tax (benefit) expense
—

(96
)
(96
)
—

128

128

Loss on disposal of assets
7,552

1,190

8,742

27,943

1,028

28,971

Stock-based compensation
—

751

751

—

8,730

8,730

Other expense
—

191

191

—

792

792

Other general and administrative expense (1)
—

149

149

—

722

722

Deferred IPO bonus expense
452

225

677

5,038

2,668

7,706

Adjusted EBITDA
$
50,013

$
(2,245
)
$
47,768

$
98,296

$
(3,641
)
$
94,655

Three months ended September 30, 2016
Nine months ended September 30, 2016
($ in thousands)
Pressure Pumping
All Other
Total
Pressure Pumping
All Other
Total
Net loss
$
(12,265
)
$
(1,333
)
$
(13,598
)
$
(34,815
)
$
(1,015
)
$
(35,830
)
Depreciation and amortization
9,274

1,516

10,790

27,905

4,764

32,669

Interest expense
—

4,550

4,550

—

15,942

15,942

Income tax benefit
—

(6,946
)
(6,946
)
—

(18,644
)
(18,644
)
(Gain)/loss on disposal of assets
5,942

(19
)
5,923

13,410

(551
)
12,859

Stock-based compensation
—

510

510

—

1,130

1,130

Gain on extinguishment of debt
—

—

—

—

(6,975
)
(6,975
)
Other expense
—

106

106

—

419

419

Adjusted EBITDA
$
2,951

$
(1,616
)
$
1,335

$
6,500

$
(4,930
)
$
1,570

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


- 10 -

PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(Unaudited)






Note 6 - Net Income (Loss) Per Share
Net income (loss) per share is determined 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 number of shares that would be outstanding assuming dilutive options and stock are converted. The table below shows the calculations for the three and nine months ended September 30, 2017 and 2016 .
Three Months Ended September 30,
Nine Months Ended September 30,
(In thousands, except for per share data)
2017
2016
2017
2016
Numerator (both basic and diluted)
Net income (loss) relevant to common stockholders
$
21,965

$
(13,598
)
$
2,535

$
(35,830
)
Denominator
Denominator for basic income (loss) per share
83,040

52,975

74,124

42,526

Dilutive effect of stock options
2,808

—

2,822

—

Dilutive effect of performance stock units
37

—

—

—

Dilutive effect of non-vested restricted stock
379

—

172

—

Denominator for diluted income (loss) per share
86,264

52,975

77,118

42,526

Basic income (loss) per common share
$
0.26

$
(0.26
)
$
0.03

$
(0.84
)
Diluted income (loss) per common share
$
0.25

$
(0.26
)
$
0.03

$
(0.84
)

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

Three Months Ended September 30,
Nine Months Ended September 30,
2017
2016
2017
2016
Stock options
789

4,646

789

4,646

Performance stock units
—

—

170

—

Non-vested restricted stock
—

372

318

372

789

5,018

1,277

5,018


Note 7 - Stock-Based Compensation

Stock Options

Effective March 4, 2013, we adopted the ProPetro Stock Option Plan pursuant to which our Board of Directors may grant stock options or other stock-based awards to key employees, consultants, and directors. The Plan, as amended, is authorized to grant up to 4,645,884 shares of common stock to be issued upon exercise of the options. The Company’s share price used to estimate the fair value of the option at the grant date was based on a combination of income and market approaches, which are highly complex and sensitive. The income approach involves the use of a discounted cash flow method, with cash flow projections discounted at an appropriate discount rate. The market approach involves the use of comparable public companies market multiples in estimating the fair value of the Company’s stock. The expected term used to calculate the fair value of all options considers the vesting date and the grant’s expiration date. The expected volatility was estimated by considering comparable public companies, and the risk free rate is based on the U.S treasury yield curve as of the grant date. The dividend assumption is based on historical experience. After becoming a public company, the market price was used to determine the market value of our common stock. Prior to 2015, we had granted a total of 3,499,228 options with an exercise price of $3.96 per option, and all options expire 10 years from the date of grant.


- 11 -
PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(Unaudited)

Note 7 - Stock-Based Compensation (Continued)

On June 14, 2013, we granted 2,799,408 stock option awards to certain key employees and directors that shall vest and become exercisable based upon the achievement of a service requirement. The options vest in 25% increments for each year of continuous service and an option becomes fully vested upon the optionee’s completion of the fourth year of service. The contractual term for the options awarded is 10 years. For the nine months ended September 30, 2017 and 2016 , we recognized $0.7 million and $0.9 million , respectively, in compensation expense related to these stock options. The fair value of each option award granted is estimated on the date of grant using the Black-Scholes option-pricing model. The fair value of the options was estimated at the date of grant using the following assumptions:

Expected volatility
45
%
Expected dividends
$
—

Expected term (in years)
6.25

Risk free rate
1.35
%

On December 1, 2013, we granted 699,820 stock option awards to certain key employees which were scheduled to vest in four substantially equal annual installments, subject to service and performance requirements and acceleration upon a change in control. As of September 30, 2016 , the performance requirement was not considered to be probable of achievement for any of the outstanding option awards and 114,456 options were forfeited during the year ended December 31, 2016 . Accordingly, we have not recognized any compensation expense related to these stock options as of September 30, 2016 . Effective March 16, 2017, we terminated the options in connection with the IPO and approved a cash bonus totaling $5.1 million to the holders of the options.

The contractual term for the options awarded is 10 years. The fair value of each option award granted is estimated on the date of grant using the Black-Scholes option-pricing model. The fair value of the options was estimated at the date of grant using the following assumptions:
Expected volatility
45
%
Expected dividends
$
—

Expected term (in years)
6.25

Risk free rate
1.83
%

On July 19, 2016, we granted 1,274,549 stock option awards to certain key employees and directors which are scheduled to vest in five substantially equal semi-annual installments commencing in December 2016, subject to a continuing services requirement. The contractual term for the options awarded is 10 years. For the nine months ended September 30, 2017 , we recognized the remaining $1.8 million in stock compensation expense related to these stock options, as the Company fully accelerated vesting of the options in connection with the IPO, and for the nine months ended September 30, 2016 , we recognized $0.2 million in stock compensation expense related to these stock options.

The fair value of each option award granted is estimated on the date of grant using the Black- Scholes option-pricing model. The fair value of the options was estimated at the date of grant using the following assumptions:
Expected volatility
55
%
Expected dividends
$
—

Expected term (in years)
5.8

Risk free rate
1.22
%

In March 2017, our shareholders approved the ProPetro 2017 Incentive Award Plan ("IAP") pursuant to which our Board of Directors may grant stock options, restricted stock units ("RSUs"), performance stock units ("PSUs"), or other stock-based awards to key employees, consultants, directors and employees. The IAP authorizes up to 5,800,000 shares of common stock to be issued under awards granted pursuant to the plan. On March 16, 2017, we granted 793,738 stock option awards to certain key employees and directors pursuant to the IAP which are scheduled to vest in four substantially equal annual installments, subject to a continuing service requirement. The contractual term for the options awarded is 10 years. For the nine months

- 12 -
PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(Unaudited)

Note 7 - Stock-Based Compensation (Continued)

ended September 30, 2017 and 2016 , we recognized $0.4 million and $0 , in stock compensation expense related to these stock option awards.

The fair value of each stock option award granted is estimated on the date of grant using the Black- Scholes option-pricing model. The fair value of the options was estimated at the date of grant using the following assumptions:
Expected volatility
18
%
Expected dividends
$
—

Expected term (in years)
6.25

Risk free rate
2.23
%

A summary of the stock option activity for the nine months ended September 30, 2017 and the year ended December 31, 2016 , is presented below.

Number
of Shares
Weighted
Average
Exercise
Price
Weighted
Average
Grant-Date
Fair Value
Outstanding at January 1, 2016
3,485,791

$
3.96

$
1.77

Granted
1,274,549

$
2.25

$
1.77

Exercised
—

$
—

$
—

Forfeited
(114,456
)
$
3.96

$
1.77

Expired
—

$
—

$
—

Canceled
—

$
—

$
—

Outstanding at December 31, 2016
4,645,884

$
3.49

$
1.77

Exercisable at December 31, 2016
2,354,466

$
3.77

$
1.77

Outstanding at January 1, 2017
4,645,884

$
3.49

$
1.77

Granted
793,738

$
14.00

$
3.35

Exercised
(226,194
)
$
3.96

$
1.77

Forfeited
(5,148
)
$
14.00

$
3.35

Expired
—

$
—

$
—

Canceled
(571,927
)
$
3.96

$
1.77

Outstanding at September 30, 2017
4,636,353

$
5.20

$
2.04

Exercisable at September 30, 2017
3,847,763

$
3.39

$
1.77


Restricted Stock Units (Non-Vested Stock) and Performance Stock Units
On September 30, 2013, our Board of Directors authorized and granted 372,335 restricted stock units (RSUs) to a key executive. Each RSU represents the right to receive one share of common stock of the Company at par value $0.001 per share. Under the terms of the award, the shares of common stock subject to the RSUs were to be paid to the grantee upon change in control, regardless of whether the grantee was affiliated with the Company on the settlement date. The fair value of the RSUs is measured as the price of the Company’s shares on the grant date, which was estimated to be $3.89 . The share price used to estimate the fair value of the RSU at the grant date was based on a combination of income and market approaches, which are highly complex and sensitive. The income approach involves the use of a discounted cash flow method, with the cash flow projections discounted at an appropriate discount rate. The market approach involves the use of comparable public companies market multiples in estimating the fair value of the Company’s stock. Effective March 22, 2017, the Board of Directors canceled these RSUs and issued 372,335 new RSUs to the grantee. These issued RSUs are effectively identical to the RSUs granted in 2013, provided, however, that the RSUs will now be payable in full on March 22, 2018. The fair value of the RSUs

- 13 -
PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(Unaudited)

Note 7 - Stock-Based Compensation (Continued)

issued on March 22, 2017, was based on the Company's stock market price at the grant date. In connection with the IPO, we fully recognized the stock compensation expense related to the re-issued RSUs.

On June 5, 2017, our Board of Directors granted 319,250 RSUs to employees, directors and executives pursuant to the 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 nine months ended September 30, 2017 and 2016 , the recorded stock compensation expense for all RSUs was $5.8 million and $0 , respectively.

The following table summarizes RSUs activity during the nine months ended September 30, 2017 :


Number of
Shares
Weighted
Average
Grant Date
Fair Value
Outstanding at January 1, 2017
372,335

$
3.89

Granted
691,585

$
13.65

Vested
—

$
—

Exercised
—

$
—

Forfeited
(1,170
)
$
13.65

Expired
—

$
—

Canceled
(372,335
)
$
3.89

Outstanding at September 30, 2017
690,415

$
13.65



Effective June 5, 2017, our Board of Directors authorized and granted performance stock unit awards to certain key employees under the IAP. The actual number of shares that may be issued under the performance stock unit awards 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 the date of our IPO through December 31, 2019. Compensation expense is recorded ratably over the corresponding requisite service period. The fair value of performance stock unit awards 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 nine months ended September 30, 2017 and 2016 the recorded stock compensation expense for the performance stock units was $0.2 million and $0 , respectively.

The following table summarizes information about the performance stock units that were outstanding at September 30, 2017 :
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

Total
—

169,635

—

—

169,635



The total stock compensation expense for the nine months ended September 30, 2017 and 2016 for all stock awards was $8.7 million and $1.1 million , respectively. The total unrecognized compensation expense as of September 30, 2017 is approximately $7.5 million , and is expected to be recognized over a weighted-average period of approximately 2.9 years.

- 14 -

PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(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 $0.07 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 , $0.09 million , $0.09 million , and $0.18 million .

For the nine months ended September 30, 2017 and 2016 , the Company paid approximately $0.21 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 the nine months ended September 30, 2017 and 2016 , the Company paid $0.14 million and $0.14 million , respectively.

At September 30, 2017 and December 31, 2016 , the Company had $0 million and $0 in payables, respectively, and approximately $0.04 million and $0.04 million in receivables, respectively, for related parties for services provided.

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.

For related party disclosure related to equity transactions with ECP, see Note 10.

Note 9 - Commitments and Contingencies
Operating Lease

We have various operating leases for office space and certain property and equipment. For the nine months ended September 30, 2017 and 2016 , we recorded operating lease expense of $ 1.0 million and $ 1.0 million , respectively. Required remaining lease payments for each fiscal year are as follows:

($ in thousands)
2017
$
116

2018
426

2019
366

2020
344

2021 and thereafter
774

Total
$
2,026


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.


- 15 -

PROPETRO HOLDING CORP. AND SUBSIDIARY
N OTES TO C ONDENSED C ONSOLIDATED F INANCIAL S TATEMENTS
(Unaudited)






Note 10 - Equity Capitalization
Credit Amendment Equity Infusion
In connection with the Term Loan and Revolving Credit Facility amendment dated June 8, 2016 (see Note 4), ECP and its related affiliates along with other shareholders infused $40.425 million of equity into the Company and we issued 18,007,328 additional shares of common stock.

Convertible Preferred Stock
On December 27, 2016, we completed a private placement offering of $170.0 million , issuing 16,999,990 shares of Series A nonparticipating convertible preferred stock, par value $0.001 per share. Costs associated with the offering were approximately $7.0 million , resulting in net proceeds to the Company of approximately $163.0 million .
As of December 31, 2016 , 16,999,990 shares of Series A convertible preferred stock were issued and outstanding, convertible into common stock at the conversion price per the private placement agreement. Upon the consummation of the IPO, the Series A Preferred stock automatically converted into common stock.
Initial Public Offering
On March 22, 2017, we consummated our 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 existing 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 the term loan, (ii) to fund the purchase of additional hydraulic fracturing fleets and ancillary equipment, and (iii) for general corporate purposes. In connection with the IPO, all 16,999,990 shares of our outstanding Series A Preferred Stock converted to common stock on a 1 :1 basis.

Additionally, on March 28, 2017, one executive and one director net settled a total of 226,194 of their exercisable stock options and received 162,212 shares of common stock .
At September 30, 2017 and December 31, 2016 , the Company had 83,039,854 and 52,627,652 shares outstanding, respectively.


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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," "may," "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.


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ITEM 2. Management's Discussion and Analysis of Financial Condition and Results of Operations
The financial information, discussion and analysis that follow should be read in conjunction with our consolidated financial statements and the related notes included in the Prospectus 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, or HHP, with a current aggregate deployed capacity of 690,000 HHP. Our fleet, which consists of 16 hydraulic fracturing fleets, has been designed to handle the highest intensity, most complex hydraulic fracturing jobs and has been 100% utilized since September 2016. During the third quarter ended September 30, 2017, we put three new hydraulic fracturing fleets into service. Subsequent to the end of this quarter, we also deployed one additional new hydraulic fracturing fleet in the fourth quarter of 2017, bringing our current total to 16, and aggregate capacity to 690,000 HHP. In addition, we have committed to acquire one new additional hydraulic fracturing fleet which is expected to be delivered before the end of the first quarter of 2018. This fleet will provide us with an incremental 45,000 HHP, bringing our aggregate capacity to 735,000 HHP by the end of the first quarter of 2018.

Through our pressure pumping segment (which also includes cementing and acidizing operations), we primarily provide hydraulic fracturing services to E&P companies in the Permian Basin. Our modern hydraulic fracturing fleet has been designed to handle Permian Basin specific operating conditions and the region's increasingly high-intensity well completions, 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 have fully maintained our equipment throughout the recent industry downturn to ensure optimal performance and reliability. Additionally, all of the hydraulic horsepower delivered over the last four years 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, Permian 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 increasing 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 reached a low of $26.19 per barrel. This decline in 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, the recovery of crude oil prices to a high in excess of $50 per barrel since December 2016 through September 2017, has driven 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 increasing

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from a low of 137 rigs in the basin as of May 2016 to 385 rigs in the basin as of September 2017, 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 frac stages per lateral and increasing amounts of proppant employed per well, have significantly increased demand for our hydraulic fracturing and other completion services.
As the Permian Basin shifts further towards more intensive horizontal drilling, operators and service providers are expected to continue to place significant focus on drilling and completion efficiencies, such as multi-well pads and zipper fracs. 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.
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., Superior Energy Services, Schlumberger 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. More recently however, with increasing levels of Delaware Basin activity, we have recently expanded our presence in the Delaware Basin in response to increasing levels of demand pull 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.

EBITDA, 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) (gain) on extinguishment of debt, (iii) stock based compensation, and (iv) 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 expenses (such as IPO bonus) 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, operating income, cash flow from operating activities or any other measure of financial performance presented in accordance with GAAP.




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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 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 September 30, 2017
Nine months ended September 30, 2017
($ in thousands)
Pressure Pumping
All Other
Total
Pressure Pumping
All Other
Total
Net income (loss)
$
28,372

$
(6,407
)
$
21,965

$
30,087

$
(27,552
)
$
2,535

Depreciation and amortization
13,637

1,108

14,745

35,228

3,374

38,602

Interest expense
—

644

644

—

6,469

6,469

Income tax (benefit) expense
—

(96
)
(96
)
—

128

128

Loss on disposal of assets
7,552

1,190

8,742

27,943

1,028

28,971

Stock-based compensation
—

751

751

—

8,730

8,730

Other expense
—

191

191

—

792

792

Other general and administrative expense (1)
—

149

149

—

722

722

Deferred IPO bonus expense
452

225

677

5,038

2,668

7,706

Adjusted EBITDA
$
50,013

$
(2,245
)
$
47,768

$
98,296

$
(3,641
)
$
94,655

Three months ended September 30, 2016
Nine months ended September 30, 2016
($ in thousands)
Pressure Pumping
All Other
Total
Pressure Pumping
All Other
Total
Net loss
$
(12,265
)
$
(1,333
)
$
(13,598
)
$
(34,815
)
$
(1,015
)
$
(35,830
)
Depreciation and amortization
9,274

1,516

10,790

27,905

4,764

32,669

Interest expense
—

4,550

4,550

—

15,942

15,942

Income tax benefit
—

(6,946
)
(6,946
)
—

(18,644
)
(18,644
)
(Gain)/loss on disposal of assets
5,942

(19
)
5,923

13,410

(551
)
12,859

Stock-based compensation
—

510

510

—

1,130

1,130

Gain on extinguishment of debt
—

—

—

—

(6,975
)
(6,975
)
Other expense
—

106

106

—

419

419

Adjusted EBITDA
$
2,951

$
(1,616
)
$
1,335

$
6,500

$
(4,930
)
$
1,570


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

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Results of Operations
We conduct our business through seven operating segments: hydraulic fracturing, cementing, acidizing, coil tubing, flowback, surface drilling, and Permian drilling. For reporting purposes, the hydraulic fracturing, cementing and acidizing 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. We expect revenues and costs of services related to our Permian drilling operating segment to comprise a lower percentage of total revenues and total costs of service in future results of operations when compared to historic results due to our increased focus on pressure pumping and other complementary service offerings. We anticipate the financial significance of this service line relative to the financial results from pressure pumping and other service offerings to continue to decline.

The following table sets forth the results of operations for the periods presented (in thousands, except for percentages):
Three Months Ended September 30,
Nine Months Ended September 30,

2017
2016
2017
2016
Revenue
$
282,730

$
116,904

$
668,153

$
272,999

Cost of services (1)
225,433

110,223

551,775

255,362

General and administrative expense (2)
11,106

5,856

38,881

17,197

Depreciation and amortization
14,745

10,790

38,602

32,669

Loss on disposal of assets
8,742

5,923

28,971

12,859

Interest expense
644

4,550

6,469

15,942

Gain on extinguishment of debt
—

—

—

(6,975
)
Other expense
191

106

792

419

Income tax expense/(benefit)
(96
)
(6,946
)
128

(18,644
)
Net income (loss)
$
21,965

$
(13,598
)
$
2,535

$
(35,830
)
​
​

​

​

​

Adjusted EBITDA (3)
$
47,768

$
1,335

$
94,655

$
1,570

Adjusted EBITDA Margin (3)
16.90
%
1.14
%
14.17
%
0.58
%




Pressure pumping segment results of operations:
Revenue
$
271,924

$
109,697

$
639,355

$
251,410

Cost of services
$
217,171

$
103,465

$
529,818

$
235,587

Adjusted EBITDA
$
50,013

$
2,951

$
98,296

$
6,500

Adjusted EBITDA Margin (4)
18.39
%
2.69
%
15.37
%
2.59
%
(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 SEPTEMBER 30, 2017 COMPARED TO THREE MONTHS ENDED SEPTEMBER 30, 2016


Revenues. Revenues increased 141.8% , or $165.8 million , to $282.7 million for the three months ended September 30, 2017 , as compared to $ 116.9 million for the three months ended September 30, 2016 . 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 147.9% , or $162.2 million , for the three months ended September 30, 2017 , as compared to the three months ended September 30, 2016 . Revenues from services other than pressure pumping increased 49.9% , or $3.6 million , for the three months ended September 30, 2017 as compared to the three months ended September 30, 2016 . 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, offset by the decrease in revenue from the idling of our Permian drilling rigs in the three months ended September 30, 2017 .
Cost of Services. Cost of services increased 104.5% , or $115.2 million , to $225.4 million for the three months ended September 30, 2017 , from $110.2 million during the three months ended September 30, 2016 . Cost of services in our pressure pumping segment increased $113.7 million for the three months ended September 30, 2017 , as compared to the three months ended September 30, 2016 . The increases were primarily attributable to higher activity levels, fleet size, coupled with an increase in personnel headcount following the increased activity levels. As a percentage of pressure pumping segment revenues, pressure pumping cost of services decreased to 79.9% for the three months ended September 30, 2017 , as compared to 94.3% for the three months ended September 30, 2016 . 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 three months ended September 30, 2017 .
General and Administrative Expenses. General and administrative expenses increased 89.7% , or $5.3 million , to $11.1 million for the three months ended September 30, 2017 , as compared to $5.9 million for the three months ended September 30, 2016 . The increase was primarily attributable to increases in legal and professional fees, insurance expense and payroll, totaling $4.5 million, and a net increase in other remaining general and administrative expenses totaling $0.7 million.
Depreciation and Amortization. Depreciation and amortization increased 36.7% , or $ 4.0 million , to $14.7 million for the three months ended September 30, 2017 , as compared to $10.8 million for the three months ended September 30, 2016 . The increase was primarily attributable to additional property and equipment purchased in 2017. We calculate depreciation of property and equipment using the straight-line method.
Loss on Disposal of Assets. Loss on the disposal of assets increased 47.6% , or $2.8 million , to $8.7 million for the three months ended September 30, 2017 , as compared to $5.9 million for the three months ended September 30, 2016 . The increase was primarily attributable to greater service intensity of jobs completed coupled with higher fleet size, activity levels and utilization of our equipment.
Interest Expense. Interest expense decreased 85.8% , or $3.9 million , to $ 0.6 million for the three months ended September 30, 2017 , as compared to $4.6 million for the three months ended September 30, 2016 . The decrease in interest expense was primarily attributable to a reduction in our average debt balance during 2017 due to the early retirement of our Term Loan and Revolving Credit Facility in the first quarter of 2017.
Other Expense. Other expense was $0.2 million for the three months ended September 30, 2017 , as compared to other expense of $ 0.1 million for the three months ended September 30, 2016 . The marginal net increase was primarily attributable to decrease in the unrealized gain resulting from the change in the fair value of our interest rate swap liability at September 30, 2017 compared to September 30, 2016 , and partially offset by a decrease in other lender related expenses.
Income Tax Expense/(Benefit). For the three months ended September 30, 2017 , we utilized the discrete effective tax rate method as allowed by Accounting Standards Codification (“ASC”) 740-270-30-18, Income Taxes - Interim Reporting to calculate its interim tax provision. The discrete method treats the year to date period as if it was the annual period and determines the income tax expense or benefit on that basis. We believe that, at this time, the use of this discrete method is more appropriate than the annual effective tax rate method as the annual effective tax rate is not reliable because small changes in estimated “ordinary” income would result in significant changes in the estimated annual effective tax rate. Total income tax benefit was $0.1 million resulting in a negative effective tax rate of 0.4% for the three months ended September 30, 2017 as compared to total income tax benefit of $6.9 million and an effective tax rate of 33.8% for the three months ended September 30, 2016 . The negative effective tax rate is primarily due to our full valuation allowance position, impact of indefinite lived assets, state tax expense and alternative minimum tax expense, which creates a deviation from the customary relationship between income tax expense (benefit) and pre-tax income/(loss).

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NINE MONTHS ENDED SEPTEMBER 30, 2017 COMPARED TO NINE MONTHS ENDED SEPTEMBER 30, 2016

Revenues. Revenues increased 144.7% , or $395.2 million , to $668.2 million for the nine months ended September 30, 2017 , as compared to $273.0 million for the nine months ended September 30, 2016 . 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 154.3% , or $387.9 million for the nine months ended September 30, 2017 as compared to the nine months ended September 30, 2016 . Revenues from services other than pressure pumping increased 33.4% , or $7.2 million , in the nine months ended September 30, 2017 , as compared to the nine months ended September 30, 2016 . The increase in revenues from services other than pressure pumping during the nine months ended September 30, 2017 was primarily attributable to the increase in revenues and customer demand for our flowback, coil tubing and surface drilling services, offset by the decrease in revenue from idling of our Permian drilling rigs.
Cost of Services. Cost of services increased 116.1% , or $296.4 million , to $551.8 million for the nine months ended September 30, 2017 , from $255.4 million during the nine months ended September 30, 2016 . Cost of services in our pressure pumping segment increased $294.2 million for the nine months ended September 30, 2017 , as compared to the nine months ended September 30, 2016 . The increases were primarily attributable to higher activity levels, coupled with an increase in personnel headcount following the increased activity levels. As a percentage of pressure pumping segment revenues, pressure pumping cost of services decreased to 82.9% for the nine months ended September 30, 2017 , as compared to 93.7% for the nine months ended September 30, 2016 . The decrease in cost of services as a percentage of revenue for the pressure pumping segment resulted from 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 nine months ended September 30, 2017 .
General and Administrative Expenses. General and administrative expenses increased 126.1% , or $21.7 million , to $38.9 million for the nine months ended September 30, 2017 , as compared to $17.2 million for the nine months ended September 30, 2016 . The increase was primarily attributable to increases in legal and professional fees, insurance expense and payroll, totaling $6.7 million, IPO bonus of $7.7 million to key employees, along with $7.6 million increase in stock compensation recorded during 2017, and partially offset by a $0.3 million decrease in other remaining general and administrative expenses. General and administrative expenses, excluding non-recurring deferred IPO bonus of $7.7 million and stock compensation compensation expense of $6.8 million , as a percentage of total revenues decreased to 3.6% for the nine months ended September 30, 2017 , as compared to 6.3% for the nine months ended September 30, 2016 , and the decrease is as a result of the higher revenue in the nine months ended September 30, 2017 .
Depreciation and Amortization. Depreciation and amortization increased 18.2% , or $ 5.9 million , to $38.6 million for the nine months ended September 30, 2017 , as compared to $32.7 million for the nine months ended September 30, 2016 . The increase was primarily attributable to additional property and equipment purchased and put into service during the nine months ended September 30, 2017 . We calculate depreciation of property and equipment using the straight-line method.
Loss on Disposal of Assets. Loss on the disposal of assets increased 125.3% , or 16.1 million , to $29.0 million for the nine months ended September 30, 2017 , as compared to $12.9 million for the nine months ended September 30, 2016 . The increase was primarily attributable to greater service intensity of jobs completed coupled with higher fleet size, activity levels and utilization of our equipment.
Interest Expense. Interest expense decreased 59.4% , or $9.5 million , to $6.5 million for the nine months ended September 30, 2017 , as compared to $15.9 million for the nine months ended September 30, 2016 . The decrease in interest expense was primarily attributable to a reduction in our average debt balance during 2017 due to the early retirement of our Term Loan and Revolving Credit Facility in the first quarter of 2017.
Other Expense. Other expense was $0.8 million for the nine months ended September 30, 2017 , as compared to $0.4 million for the nine months ended September 30, 2016 . The increase was primarily attributable to an increase in lenders related expenses, non-recurring listing related expenses, and partially offset by an increase in the unrealized gain resulting from the change in the fair value of our interest rate swap liability at September 30, 2017 compared to September 30, 2016 .
Gain on Extinguishment of Debt. There was no debt extinguishment gain or loss during the nine months ended September 30, 2017 , compared to the gain on extinguishment of debt, net of cost, of $7.0 million during the nine months ended September 30, 2016 . The gain on extinguishment of debt during 2016 was as a result of the auction process with our lenders to repurchase $37.5 million of our Term Loan at a 20% discount to par value.
Income Tax Expense/(Benefit). For the nine months ended September 30, 2017 , 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

- 23 -

and determines the income tax expense or benefit on that basis. The Company believes that, at this time, the use of this discrete method is more appropriate than the annual effective tax rate method as the annual effective tax rate is not reliable because small changes in estimated “ordinary” income would result in significant changes in the estimated annual effective tax rate. Total income tax expense was $0.1 million resulting in an effective tax rate of 4.8% for the nine months ended September 30, 2017 , compared to total income tax benefit of $18.6 million and an effective tax rate of 34.2% for the nine months ended September 30, 2016 . The change in effective tax rate is primarily due to the Company’s full valuation allowance position, impact of indefinite lived assets, alternative minimum tax expense and state tax expense.

Liquidity and Capital Resources
Effective as of 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 using the proceeds (i) to repay the remaining balance on our term loan, (ii) to acquire additional hydraulic fracturing fleets and (iii) for general corporate purposes.
On March 22, 2017, we entered into a new revolving credit facility with a $150 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 1.0 x 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 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.
As of September 30, 2017 , our cash and cash equivalents were $51.0 million , as compared to $133.6 million at December 31, 2016 . 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 continue to fund our operations, support organic 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.

Working Capital
Working capital is the amount by which current assets exceed current liabilities, and is a measure of our ability to pay our liabilities as they become due. The following table presents the components of our working capital as of September 30, 2017 compared to December 31, 2016 .


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($ in thousands)
September 30, 2017
December 31, 2016
Current Assets:
Cash and cash equivalents
$
51,008

$
133,596

Accounts receivable - net of allowance for doubtful accounts
160,047

115,179

Inventories
9,148

4,713

Prepaid expenses
5,543

4,608

Other current assets
975

6,684

Total current assets
$
226,721

$
264,780

Current Liabilities:
Accounts payable
$
181,660

$
129,093

Accrued liabilities
11,074

13,619

Current portion of long-term debt
7,441

16,920

Accrued interest payable
86

109

Total current liabilities
$
200,261

$
159,741

Working capital
$
26,460

$
105,039

Our working capital totaled $26.5 million and $105.0 million at September 30, 2017 and December 31, 2016 , respectively. The decrease in working capital is primarily attributable to our use of cash for operating, investing and financing activities.
Cash and Cash Flows
Our cash and cash equivalents were $51.0 million and $133.6 million at September 30, 2017 and December 31, 2016 , respectively.
The following table sets forth the historical cash flows for the nine months ended September 30, 2017 and 2016 :
Nine Months Ended September 30,
($ in thousands)
2017
2016
Net cash provided by (used in):
Operating activities
$
78,673

$
(5,652
)
Investing activities
$
(189,583
)
$
(18,156
)
Financing activities
$
28,322

$
(5,214
)
Operating Activities
Net cash provided by operating activities was $78.7 million for the nine months ended September 30, 2017 , compared to net cash used in operating activities of $5.7 million for the nine months ended September 30, 2016 . The net increase of $84.3 million was primarily due to increase 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 $189.6 million for the nine months ended September 30, 2017 , from $18.2 million during the nine months ended September 30, 2016 . The increase was primarily attributable to the additional hydraulic fracturing fleets and other ancillary equipment purchased during the period, and a slight increase in maintenance capital expenditures, during the nine months ended September 30, 2017 , compared to the nine months ended September 30, 2016 .
Financing Activities
Net cash provided by financing activities was $28.3 million for the nine months ended September 30, 2017 , and net cash used in financing activities was $5.2 million for the nine months ended September 30, 2016 . The net increase in cash provided was primarily due to the receipt of $185.5 million of IPO proceeds, borrowings of $27.1 million , partially offset by payment of IPO costs of $15.1 million , repayment of insurance financing of $2.9 million , debt issuance cost of $1.7 million and $164.6 million in repayment of borrowings, during the nine months ended September 30, 2017 , compared to net cash used of $42.2

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million for repayment of borrowings, repayment of insurance financing of $2.8 million , debt extinguishment and issuance cost of $0.6 million , offset by the equity capitalization proceeds of $40.4 million during the nine months ended September 30, 2016 .
Off-Balance Sheet Arrangements
We had no off-balance sheet arrangements as of September 30, 2017 .
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 originally effective for annual periods beginning after December 15, 2016, using either the retrospective or cumulative effect transition method. On August 12, 2015, the FASB issued ASU No. 2015-14, which defers the effective date of the revenue standard, ASU No. 2014-09, by one year for all entities and permits early adoption on a limited basis. We have completed our preliminary evaluation of ASU No. 2014-09, and the adoption of this guidance will not materially affect our revenue recognition. However, there will be additional disclosures on our consolidated financial statements relating to the adoption of this standard.
In July 2015, the FASB issued ASU No. 2015-11, Simplifying the Measurement of Inventory, which requires entities to measure most inventory "at the lower of cost and net realizable value," thereby simplifying the current guidance under which an entity must measure inventory at the lower of cost or market. ASU No. 2015-11 does not apply to inventories that are measured by using either the last-in, first-out method or the retail inventory method. The amendments in ASU No. 2015-11 are effective for fiscal years beginning after December 15, 2016. The ASU became effective for us in 2017 and the adoption of this guidance did not materially affect our consolidated financial statements.
In February 2016, the FASB issued ASU No. 2016-02, Leases , a new standard on accounting for leases. The ASU introduces a lessee model that brings most leases on the balance sheet. The new standard also aligns many of the underlying principles of the new lessor model with those in the current accounting guidance as well as the FASB’s new revenue recognition standard. 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 disclosures along with specific quantitative disclosures to better enable users of financial statements to assess the amount, timing, and uncertainty of cash flows arising from leases. The new standard is effective for annual reporting periods beginning after December 15, 2018, including periods within that reporting period, using a modified retrospective approach. Early adoption is permitted. We have not completed an evaluation of the impact the pronouncement will have on our consolidated financial statements and related disclosures.
In March 2016, the FASB issued ASU No. 2016-09, Compensation- Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting, which modifies several aspects of the accounting for share-based payment transactions including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The new standard is effective for fiscal years and interim periods beginning after December 15, 2016, with early adoption permitted. The ASU became effective for us in 2017 and the adoption of this guidance did not materially affect our consolidated financial statements.
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.
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 oil and natural gas and expectations about future prices. For many years, oil and natural gas prices and markets have been extremely volatile. Prices are affected by many factors beyond our control. Oil prices declined significantly close to the end of the second half of 2014. The closing price of 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, oil prices have recovered in the third quarter of 2016, and reaching a high in excess $50 during the third quarter of 2017. As a result of the recent recovery in oil prices, our industry has

- 26 -

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 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 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 September 30, 2017 , 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 Prospectus.
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, principal financial officer and principal accounting 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, principal financial officer and principal accounting officer concluded that our disclosure controls and procedures were effective at the reasonable assurance level as of September 30, 2017 .
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 September 30, 2017 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 prospectus dated March 16, 2017, and filed with the SEC pursuant to Rule 424(b)(4) under the Securities Act of 1933, as amended, on March 20, 2017, 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.

- 30 -

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 2, 2017
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)

- 31 -

EXHIBIT INDEX
3.1
3.2
31.1
31.2
32.1
32.2
* 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.

- 32 -
TABLE OF CONTENTS
Part I Financial InformationItem 1. Financial StatementsNote 1 - Basis Of PresentationNote 2 - Recently Issued Accounting StandardsNote 2 - Recently Issued Accounting Standards (continued)Note 3 - Fair Value MeasurementsNote 3 - Fair Value Measurement (continued)Note 4 - Long-term DebtNote 4 - Long-term Debt (continued)Note 5 - Reportable Segment InformationNote 5- Reportable Segment Information (continued)Note 6 - Net Income (loss) Per ShareNote 7 - Stock-based CompensationNote 7 - Stock-based Compensation (continued)Note 8 - Related-party TransactionsNote 9 - Commitments and ContingenciesNote 10 - Equity CapitalizationItem 2. Management's Discussion and Analysis Of Financial Condition and Results Of OperationsItem 3. Quantitative and Qualitative Disclosures About Market RiskItem 4. Controls and ProceduresPart II Other InformationItem 1. Legal ProceedingsItem 1A. Risk FactorsItem 2. Unregistered Sales Of Equity Securities and Use Of ProceedsItem 3. Defaults Upon Senior SecuritiesItem 4. Mine Safety DisclosuresItem 5. Other InformationItem 6. Exhibits

Exhibits

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 Companys 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.