Edgar Filing: BASIC ENERGY SERVICES INC

Document

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

______________________________________________________________________________________________________________________________________________

Form 10-Q

______________________________________________________________________________________________________________________________________________

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

For the quarterly period ended June 30, 2018

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

For the transition period from to

Commission File Number 001-32693

______________________________________________________________________________________________________________________________________________

Basic Energy Services, Inc.

(Exact name of registrant as specified in its charter)

______________________________________________________________________________________________________________________________________________


Delaware			54-2091194
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

801 Cherry Street, Suite 2100 Fort Worth, Texas			76102
(Address of principal executive offices)			(Zip code)

(817) 334-4100

(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 ☒ 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 ☒ No ☐

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


Large accelerated filer	☐	Accelerated filer	☒

Non-accelerated filer	☐ (Do not check if a smaller reporting company)	Smaller reporting company	☐

		Emerging growth company	☐

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

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

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court. Yes ☒ No ☐

There were 26,470,750 shares of the registrant’s common stock outstanding as of August 2, 2018.

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BASIC ENERGY SERVICES, INC.

Index to Form 10-Q


Part I. FINANCIAL INFORMATION			4
Item 1. Financial Statements			4
Consolidated Balance Sheets as of June 30 , 2018 (Unaudited) and December 31, 2017			4
Consolidated Statements of Operations for the three and six months ended June 30 , 2018 and 2017 (Unaudited)			5
Consolidated Statements of Stockholders' Equity for the six months ended June 30, 2018 (Unaudited)			6
Consolidated Statements of Cash Flows for the six months ended June 30 , 2018 and 2017 (Unaudited)			7
Notes to the Unaudited Consolidated Financial Statements			8
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			19
Management’s Overview			20
Segment Overview			21
Operating Cost Overview			23
Critical Accounting Policies and Estimates			24
Results of Operations			24
Liquidity and Capital Resources			26
Other Matters			28
Item 3. Quantitative and Qualitative Disclosures About Market Risk			28
Item 4. Controls and Procedures			28
Part II. OTHER INFORMATION			28
Item 1. Legal Proceedings			28
Item 1A. Risk Factors			29
Item 2 . Unregistered Sales of Equity Se curities and Use of Proceeds			29
Item 6. Exhibits			30
Signatures			30

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CAUTIONARY STATEMENT

REGARDING FORWARD-LOOKING STATEMENTS

This quarterly report contains certain statements that are, or may be deemed to be, “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, or the Exchange Act. We have based these forward-looking statements largely on our current expectations and projections about future events and financial trends affecting the financial condition of our business. These forward-looking statements are subject to a number of risks, uncertainties and assumptions, including, among other things, the risk factors discussed in this quarterly report and in our most recent Annual Report on Form 10-K and other factors, most of which are beyond our control.

The words “believe,” “may,” “estimate,” “continue,” “anticipate,” “intend,” “plan,” “expect,” “indicate” and similar expressions are intended to identify forward-looking statements. All statements other than statements of current or historical fact contained in this quarterly report are forward-looking statements. Although we believe that the forward-looking statements contained in this quarterly report are based upon reasonable assumptions, the forward-looking events and circumstances discussed in this quarterly report may not occur and actual results could differ materially from those anticipated or implied in the forward-looking statements.

Important factors that may affect our expectations, estimates or projections include:

• a decline in, or substantial volatility of, oil or natural gas prices, and any related changes in expenditures by our customers;

• the effects of future acquisitions on our business;

• changes in customer requirements in markets or industries we serve;

• the ability to operate our business following emergence from bankruptcy;

• availability and cost of equipment;

• competition within our industry;

• general economic and market conditions;

• our access to current or future financing arrangements;

• operational hazards inherent in the oil and gas industry;

• our ability to replace or add workers at economic rates; and

• environmental and other governmental regulations.

Our forward-looking statements speak only as of the date of this quarterly report. Should one or more of these risks or uncertainties materialize, or should any of our assumptions prove incorrect, actual results may vary in material respects from those projected in the forward-looking statements contained herein. Unless otherwise required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

This quarterly report includes market share data, industry data and forecasts that we obtained from internal company surveys (including estimates based on our knowledge and experience in the industry in which we operate), market research, consultant surveys, publicly available information, industry publications and surveys. These sources include Baker Hughes Incorporated, the Association of Energy Service Companies, and the Energy Information Administration of the U.S. Department of Energy. Industry surveys and publications, consultant surveys and forecasts generally state that the information contained therein has been obtained from sources believed to be reliable. Although we believe such information is accurate and reliable, we have not independently verified any of the data from third-party sources cited or used for our management’s industry estimates, nor have we ascertained the underlying economic assumptions relied upon therein. Statements as to our position relative to our competitors or as to market share refer to the most recent available data.

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PART I — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

Basic Energy Services, Inc.

Consolidated Balance Sheets

(in thousands, except share data)


	June 30, 2018		December 31, 2017
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	30,683	$	38,520
Restricted cash	47,125		47,703
Trade accounts receivable, net of allowance of $1,519 and $1,523, respectively	163,248		148,444
Accounts receivable - related parties	23		22
Income tax receivable	1,587		1,878
Inventories	38,657		36,403
Prepaid expenses	17,552		22,353
Other current assets	4,223		4,292

Total current assets	303,098		299,615
Property and equipment, net	480,552		502,579
Deferred debt costs, net of amortization	2,511		2,497

Intangible assets, net of amortization	3,102		3,221
Other assets	12,971		12,568
Total assets	$	802,234	$	820,480
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable	$	90,268	$	80,518
Accrued expenses	60,042		51,973
Current portion of long-term debt, net of discounts of $990 and $1,657, respectively	48,882		55,997
Other current liabilities	4,168		2,469
Total current liabilities	203,360		190,957
Long-term debt, net of discounts and deferred financing costs of $8,143 and $10,244, respectively	279,032		259,242
Deferred tax liabilities	—		78
Other long-term liabilities	36,691		31,550

Stockholders' equity:
Preferred stock; $0.01 par value; 5,000,000 shares authorized; none designated or issued at March 31, 2018 and December 31, 2017	—		—
Common stock; $0.01 par value; 80,000,000 shares authorized; 26,644,130 shares issued and 26,470,750 shares outstanding at June 30, 2018; 26,371,572 shares issued and 26,219,129 shares outstanding at December 31, 2017	266		264
Additional paid-in capital	453,907		439,517
Accumulated deficit	(167,259)		(96,674)
Treasury stock, at cost, 173,380 and 152,443 shares at June 30, 2018 and December 31, 2017, respectively	(3,763)		(4,454)
Total stockholders' equity	283,151		338,653
Total liabilities and stockholders' equity	$	802,234	$	820,480

See accompanying notes to unaudited consolidated financial statements.

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Basic Energy Services, Inc.

Consolidated Statements of Operations

(Unaudited)

(in thousands, except per share amounts)


	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017

Revenues:
Completion and remedial services	$	126,948	$	107,385	$	244,545	$	187,817
Well servicing	64,405		53,054		121,942		101,672
Water logistics	59,679		50,740		116,188		100,946

Contract drilling	2,337		2,117		5,359		4,880
Total revenues	253,369		213,296		488,034		395,315
Expenses:
Completion and remedial services	100,528		81,199		190,187		148,451
Well servicing	49,680		41,796		97,871		82,712
Water logistics	44,008		41,580		84,931		83,118

Contract drilling	1,743		1,863		4,286		4,271
General and administrative, including stock-based compensation of $9,626 and $6,275 in the three months ended June 30, 2018 and 2017 and $16,424 and $10,723 for the six months ended June 30, 2018 and 2017, respectively	51,460		36,037		92,468		70,241

Depreciation and amortization	31,161		25,956		61,396		51,369

(Gain) loss on disposal of assets	1,921		(223)		3,700		(690)
Total expenses	280,501		228,208		534,839		439,472
Operating loss	(27,132)		(14,912)		(46,805)		(44,157)
Other income (expense):
Interest expense	(12,806)		(9,179)		(24,089)		(18,289)
Interest income	60		6		87		18

Other income	102		144		441		235
Loss before income taxes	(39,776)		(23,941)		(70,366)		(62,193)
Income tax benefit (expense)	(278)		—		(219)		(374)
Net loss	$	(40,054)	$	(23,941)	$	(70,585)	$	(62,567)
Loss per share of common stock:
Basic	$	(1.51)	$	(0.92)	$	(2.67)	$	(2.41)
Diluted	$	(1.51)	$	(0.92)	$	(2.67)	$	(2.41)

See accompanying notes to unaudited consolidated financial statements.

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Basic Energy Services, Inc.

Consolidated Statements of Stockholders’ Equity

(in thousands, except share data)


				Additional						Total
	Common Stock			Paid-In		Treasury		Accumulated		Stockholders'
	Shares	Amount		Capital		Stock		Deficit		Equity
Balance - December 31, 2017	26,371,572	$	264	$	439,517	$	(4,454)	$	(96,674)	$	338,653
Issuance of stock	272,558	2		—		—		—		2
Amortization of share-based compensation	—	—		16,424		—		—		16,424
Treasury stock, net	—	—		(2,034)		691		—		(1,343)

Net loss	—	—		—		—		$	(70,585)	(70,585)
Balance - June 30, 2018	26,644,130	$	266	$	453,907	$	(3,763)	$	(167,259)	$	283,151

See accompanying notes to unaudited consolidated financial statements.

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Basic Energy Services, Inc.

Consolidated Statements of Cash Flows

(Unaudited)

(in thousands)


	Six Months Ended June 30,
	2018		2017

Cash flows from operating activities:
Net loss	$	(70,585)	$	(62,567)
Adjustments to reconcile net loss to net cash
provided by (used in) operating activities:
Depreciation and amortization	61,396		51,369


Accretion on asset retirement obligation	83		79
Change in allowance for doubtful accounts	(4)		1,751
Amortization of deferred financing costs	372		19
Amortization of debt discounts	2,742		3,862
Non-cash compensation	16,424		10,723
(Gain) loss on disposal of assets	3,700		(690)
Deferred income taxes	(78)		389
Changes in operating assets and liabilities, net of acquisitions:
Accounts receivable	(14,801)		(43,562)
Inventories	(2,254)		(989)
Income tax receivable	292		1
Prepaid expenses and other current assets	6,458		(5,958)
Other assets	(403)		(524)
Accounts payable	6,808		26,841
Other liabilities	6,905		(265)
Accrued expenses	8,069		6,128
Net cash provided by (used in) operating activities	25,124		(13,393)
Cash flows from investing activities:
Purchase of property and equipment	(31,697)		(33,745)
Proceeds from sale of assets	999		4,976


Net cash used in investing activities	(30,698)		(28,769)
Cash flows from financing activities:
Payments of debt	(27,140)		(22,266)
Proceeds from debt	26,000		—


Shares added to treasury stock as a result of net share settlements due to vesting of restricted stock	(1,341)		(38)


Deferred loan costs and other financing activities	(360)		(162)
Net cash used in financing activities	(2,841)		(22,466)
Net decrease in cash, cash equivalents and restricted cash	(8,415)		(64,628)
Cash, cash equivalents and restricted cash - beginning of period	86,223		101,304
Cash, cash equivalents and restricted cash - end of period	$	77,808	$	36,676

See accompanying notes to unaudited consolidated financial statements.

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BASIC ENERGY SERVICES, INC.

Notes to Consolidated Financial Statements

June 30, 2018 (unaudited)

1. Basis of Presentation and Nature of Operations

Basis of Presentation

The accompanying unaudited consolidated financial statements of Basic Energy Services, Inc. and subsidiaries (“Basic” or the “Company”) have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial reporting. Accordingly, they do not include all of the information and notes required by accounting principles generally accepted in the United States for complete financial statements. Certain information relating to our organization and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted in this Quarterly Report on Form 10-Q in accordance with GAAP and financial statement requirements promulgated by the U.S. Securities and Exchange Commission (“SEC”). The notes to the consolidated financial statements (unaudited) should be read in conjunction with the notes to the consolidated financial statements contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017. In the opinion of management, all adjustments which are of a normal recurring nature considered necessary for a fair presentation have been made in the accompanying unaudited financial statements.

Liquidity and Capital Resources

As of June 30, 2018, our primary capital resources were cash flows from operations, utilization of capital leases and borrowings under our accounts receivable securitization facility (the “New ABL Facility”) which had aggregate commitments of $150.0 million as of June 30, 2018. As of June 30, 2018, we had $90.0 million in borrowings under the New ABL Facility compared to $64.0 million at December 31, 2017. At June 30, 2018, we had unrestricted cash and cash equivalents of $30.7 million compared to $38.5 million as of December 31, 2017. An additional amount of $47.1 million of our cash is classified as restricted cash. Including the availability of $14.7 million under the New ABL Facility, we currently have $45.4 million in total liquidity. For further discussion see Note 5, "Long-Term Debt and Interest Expense".

Nature of Operations

Basic provides a wide range of well site services to oil and natural gas drilling and producing companies, including completion and remedial services, water logistics, well servicing and contract drilling. These services are primarily provided using Basic’s fleet of equipment. Basic’s operations are concentrated in the major United States onshore oil and gas producing regions in Texas, New Mexico, Oklahoma, North Dakota, Wyoming, Arkansas, Kansas, Louisiana, California, the Rocky Mountains and Appalachia.

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of our wholly owned subsidiaries and our variable interest entity for which we hold a majority voting interest. All intercompany transactions and balances have been eliminated.

Estimates, Risks and Uncertainties

Preparation of the accompanying consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amount of assets, liabilities, revenue, and expenses. Critical accounting estimates are those in which significant judgment is used, and the impact of any changes in estimates would have a significant effect on our consolidated financial statements. Actual results and outcomes may vary from management's estimates and assumptions. Areas where critical accounting estimates are made by management include litigation and self-insured risk reserves.

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2. Cash, Cash Equivalents and Restricted Cash

The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the unaudited condensed consolidated balance sheets that sum to the total of the same amounts shown in the unaudited statements of cash flows (in thousands):


	June 30,
	2018		2017
Cash and cash equivalents	$	30,683	$	34,244
Restricted cash	47,125		2,432
Total cash, cash equivalents and restricted cash	$	77,808	$	36,676

The Company’s restricted cash includes cash balances which are legally or contractually restricted to use. The Company’s restricted cash is included in current assets as of June 30, 2018 and 2017, respectively, and includes primarily cash used to collateralize insurance reserves.

3. Property and Equipment

Property and equipment consisted of the following (in thousands):


	June 30, 2018		December 31, 2017
Land	$	21,297	$	21,217
Buildings and improvements	40,377		40,043
Well service units and equipment	121,452		113,657
Frac equipment/test tanks	120,639		111,172
Pumping equipment	99,358		96,844
Water logistics equipment	80,490		79,711
Disposal facilities	54,936		51,363
Rental equipment	57,654		53,926
Light vehicles	23,972		19,869
Contract drilling equipment	11,424		10,967
Other	4,121		4,092
Construction equipment	2,438		2,338
Brine and fresh water stations	2,688		2,704
Software	831		817
	641,677		608,720
Less accumulated depreciation and amortization	161,125		106,141
Property and equipment, net	$	480,552	$	502,579

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Basic is obligated under various capital leases for certain vehicles and equipment that expire at various dates during the next five years. The gross amount of property and equipment and related accumulated amortization recorded under capital leases and included above consists of the following (in thousands):


	June 30, 2018		December 31, 2017
Pumping equipment	$	56,425	$	56,225
Water logistics equipment	42,083		40,097
Light vehicles	16,283		12,160
Contract drilling equipment	818		783
Well service units and equipment	98		262
Construction equipment	378		378
Rental equipment	572		—
	116,657		109,905
Less accumulated amortization	31,058		18,445
Property and equipment under capital lease, net	$	85,599	$	91,460

Amortization of assets held under capital leases is included in depreciation and amortization expense in the consolidated statements of operations. Amortization amounts consisted of the following (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017

Lease amortization expense	$	7,240	$	3,890	$	14,360	$	7,590

4. Intangible Assets

Basic had trade names of $3.4 million as of June 30, 2018 and December 31, 2017. Trade names have a 15-year life and are tested for impairment when triggering events are identified.

Basic’s intangible assets were as follows (in thousands):


	June 30, 2018		December 31, 2017


Trade names	$	3,410	$	3,410
Other intangible assets	48		48
	$	3,458	$	3,458
Less accumulated amortization	356		237
Intangible assets subject to amortization, net	$	3,102	$	3,221

Amortization expense of intangible assets for the three months ended June 30, 2018 and 2017 was as follows (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017

Intangible amortization expense	$	60	$	60	$	118	$	119

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5. Long-Term Debt and Interest Expense

Long-term debt consisted of the following (in thousands):


	June 30, 2018		December 31, 2017
Credit facilities:
Term Loan	$	161,700	$	162,525
New ABL Facility	90,000		64,000
Capital leases and other notes	85,347		100,615
Unamortized discounts, premiums, and deferred financing costs	(9,133)		(11,901)
Total principal amount of debt instruments, net	327,914		315,239
Less current portion	48,882		55,997
Long-term debt	$	279,032	$	259,242

Debt Discounts

The following discounts on debt represent the unamortized discount to fair value of our Amended and Restated Term Loan Credit Agreement (the "Term Loan Agreement") and the short-term and long-term portions of the fair value discount of capital leases (in thousands):


	June 30, 2018		December 31, 2017
Unamortized discount on Term Loan	$	8,003	$	9,187
Unamortized discount on Capital Leases - short-term	990		1,657
Unamortized discount on Capital Leases - long-term	—		891
Unamortized deferred financing costs	140		166
	$	9,133	$	11,901

On April 11, 2018, the Company entered into Amendment No. 2 (“Amendment No. 2”) to the New ABL Facility. Among other things, Amendment No. 2 (i) increased the aggregate commitments under the Credit Agreement from $120 million to $150 million and (ii) added Morgan Stanley Senior Funding, Inc. as a lender and amended the commitment schedule to the Credit Agreement to reflect the same.

As of June 30, 2018, Basic had $44.0 million of letters of credit outstanding secured by restricted cash borrowed under the New ABL Facility. Basic had borrowings under the New ABL Facility of $90 million as of June 30, 2018, giving Basic $14.7 million of available borrowing capacity under the New ABL Facility.

Basic’s interest expense for the three and six months ended June 30, 2018 and 2017, consisted of the following (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017

Cash payments for interest	$	7,564	$	8,040	$	16,142	$	9,308
Commitment and other fees paid	994		170		1,803		187
Amortization of debt issuance costs and discounts	1,463		2,321		3,114		3,881
Change in accrued interest	2,769		(1,364)		2,990		4,878

Other	16		12		40		35
	$	12,806	$	9,179	$	24,089	$	18,289

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6. Fair Value Measurements

The following is a summary of the carrying amounts, net of discounts, and estimated fair values of our financial instruments as of June 30, 2018 and December 31, 2017:


	Fair Value	June 30, 2018				December 31, 2017
	Hierarchy Level	Carrying Amount		Fair Value		Carrying Amount		Fair Value
		(In thousands)
Term Loan	3	$	153,697	$	159,969	$	153,338	$	162,052

The fair value of the Term Loan Agreement is based upon our discounted cash flows model using a third-party discount rate. The carrying amount of our New ABL Facility approximates fair value due to its variable-rate characteristics.

The carrying amounts of cash and cash equivalents, trade accounts receivable, accounts receivable-related parties, capital leases, accounts payable and accrued expenses approximate fair value due to the short maturities of these instruments.

7. Commitments and Contingencies

Environmental

Basic is subject to various federal, state and local environmental laws and regulations that establish standards and requirements for protection of the environment. Basic cannot predict the future impact of such standards and requirements, which are subject to change and can have retroactive effectiveness. Basic continues to monitor the status of these laws and regulations. Management believes that the likelihood of any of these items resulting in a material adverse impact to Basic’s financial position, liquidity, capital resources or future results of operations is remote.

Currently, Basic has not been fined, cited or notified of any environmental violations that would have a material adverse effect upon its financial position, liquidity or capital resources. However, management does recognize that by the very nature of its business, material costs could be incurred in the near term to bring Basic into total compliance with the laws and regulations. The amount of such future expenditures is not determinable due to several factors, including the unknown magnitude of possible contamination, the unknown timing and extent of the corrective actions which may be required, the determination of Basic’s liability in proportion to other responsible parties and the extent to which such expenditures are recoverable from insurance or indemnification.

Litigation

From time to time, Basic is a party to litigation or other legal proceedings that Basic considers to be a part of the ordinary course of business. Basic is not currently involved in any legal proceedings that it considers probable or reasonably possible, individually or in the aggregate, to result in a material adverse effect on its financial condition, results of operations or liquidity.

Sales and Use Tax Audit

In 2014, Basic was notified by the Texas State Comptroller’s office that a sales and use tax audit for the period from 2010 through 2013 would be conducted. A preliminary report has been issued in the second quarter of 2018 for this audit, and Basic will appeal the preliminary report through the redetermination process. Based on our analysis, the potential liability associated with this audit ranges from $6.0 million to $24.0 million. An accrual for the estimated liability of $6.0 million has been recorded in Basic’s financial statements as general and administrative expense and the related interest associated with the taxes of $1.5 million is included in interest expense. This range could potentially change in future periods as the appeals and redetermination process progresses.

Self-Insured Risk Accruals

Basic is self-insured up to retention limits as it relates to workers’ compensation, general liability claims, and medical and dental coverage of its employees. Basic generally maintains no physical property damage coverage on its workover rig fleet, with the exception of certain of its 24-hour workover rigs and newly manufactured rigs. Basic has deductibles per occurrence for workers’ compensation, general liability claims, automobile liability and medical coverage of $5.0 million, $1.0 million, $1.0 million, and $425,000, respectively. Basic maintains accruals in the accompanying consolidated balance sheets related to self-insurance retentions based upon third-party data and claims history.

At June 30, 2018 and December 31, 2017, self-insured risk accruals totaled approximately $30.4 million, net of $865,000 receivable for medical and dental coverage, and $30.3 million, net of $971,000 receivable for medical and dental coverage, respectively.

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8. Stockholders’ Equity

Common Stock

In February 2018, Basic granted certain members of management 203,625 performance-based restricted stock units and 203,625 restricted stock units, which each vest over a three-year period.

Treasury Stock

Basic has acquired treasury shares through net share settlements for payment of payroll taxes upon the vesting of certain restricted stock units and awards. Basic acquired a total of 77,431 shares of common stock through net share settlements during the first six months of 2018 and issued 56,494 shares from treasury stock for accelerated vestings and stock grants in the first six months of 2018. Basic acquired 1,032 shares of common stock through net share settlements during the first six months of 2017.

9. Incentive Plan

The following table reflects compensation activity related to the management incentive plan for the three and six-month periods ended June 30, 2018 (dollar amounts in thousands):


	Compensation expense for three months ended June 30, 2018		Compensation expense for six months ended June 30, 2018		Unrecognized compensation expense		Weighted average remaining life	Fair value of share based awards vested





Restricted stock awards and restricted stock units	$	8,025	$	13,757	$	23,448	1.7	$	4,882
Stock options	$	1,601	$	2,667	$	5,203	8.6	$	—

Stock Option Awards

The fair value of each stock option is estimated on the date of grant using the Black-Scholes-Merton option-pricing model. Stock options granted under the Company's management incentive plan expire ten years from the date they are granted, and vest over a three-year service period.

The following table reflects changes during the six-month period and a summary of stock options outstanding at June 30, 2018:


				Weighted
				Average
		Weighted		Remaining	Aggregate
	Number of	Average		Contractual	Intrinsic
	Options	Exercise		Term	Value
	Granted	Price		(Years)	(000's)
Non-statutory stock options:
Outstanding, beginning of period	654,016	$	39.23
Options granted	—	—
Options forfeited	(17,266)	39.23
Options exercised	—	—

Outstanding, end of period	636,750	$	39.23	8.6	$	—
Exercisable, end of period	222,354	$	39.23	8.6	$	—
Vested or expected to vest, end of period	414,396	$	39.23	8.6	$	—

There were no stock options exercised during the six months ended June 30, 2018 and 2017.

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Restricted Stock Unit Awards

A summary of the status of Basic’s non-vested restricted stock units at June 30, 2018 and changes during the six months ended June 30, 2018 are presented in the following table:


		Weighted Average
	Number of	Grant Date Fair
Non-vested Units	Shares	Value Per Share
Non-vested at beginning of period	1,097,010	$	36.35
Granted during period	455,650	16.01
Vested during period	(284,904)	36.21
Forfeited during period	(54,134)	28.21
Non-vested at end of period	1,213,622	$	29.11

Restricted Stock Awards

On May 21, 2018, Basic’s Board of Directors, the "Board", approved grants of restricted stock awards to non-employee members of the Board. The number of restricted shares granted was 48,400. These grants are subject to vesting over a period of ten months and are subject to accelerated vesting under certain circumstances.

Phantom Stock Awards

On February 8, 2018, the Compensation Committee of the Board approved grants of phantom restricted stock awards to certain key employees. Phantom shares are recorded as a liability at their current market value and are included in other current liabilities. The number of phantom shares issued on February 8, 2018 was 82,170. These grants remain subject to vesting annually in one-third increments over a three-year period, with the first portion vesting on March 15, 2019, and are subject to accelerated vesting in certain circumstances.

10. Related Party Transactions

Basic had receivables from employees of approximately $23,000 and $22,000 as of June 30, 2018 and December 31, 2017, respectively.

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11. Revenues

Our revenues are generated by services, which are consumed as provided by our customers on their sites. As a decentralized organization, contracts for our services are negotiated on a regional level and are on a per job basis, with jobs being completed in a short period of time, usually one day or up to a week. Revenue is recognized as performance obligations have been completed on a daily basis either as Accounts Receivable or Work-in-Process ("WIP"), when all of the proper approvals are obtained.

A small percentage of our jobs may require performance obligations which extend over a longer period of time and are not invoiced until all performances obligations in the contract are complete, such as, drilling or plugging a well, fishing services, and pad site preparation jobs. Because these jobs are performed on the customer's job site, and we are contractually entitled to bill for our services performed to date, revenues for these service lines are recognized on a daily basis as services are performed and recorded as Contract Assets rather than a WIP or Accounts Receivable. Contract Assets are typically invoiced within 30 to 60 days of recognizing revenue.

As of June 30, 2018, accounts receivable related to products and services were $163.2 million. At June 30, 2018 and December 31, 2017, the Company had $1.8 million and $2.4 million of contract assets, respectively, and had no contract liabilities or deferred contract costs recorded on the consolidated balance sheet.

Basic does not have any long-term service contracts; nor do we have revenue expected to be recognized in any future year related to remaining performance obligations or contracts with variable consideration related to undelivered performance obligations.

The following table sets forth certain financial information with respect to Basic’s disaggregation of revenues by geographic location and type (in thousands):

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	Reportable Segments

	Completion & Remedial Services		Well Servicing		Water Logistics		Contract Drilling		Total
Three Months Ended June 30, 2018
Primary Geographical Markets
Permian Basin	$	43,323	$	30,364	$	32,066	$	2,466	$	108,219
Texas Gulf Coast	236		7,338		8,614		—		16,188
ArkLaTex & Mid-Continent	56,144		12,731		11,616		—		80,491
Rocky Mountain	27,198		6,911		8,833		—		42,942
Eastern USA	1,267		2,286		—		—		3,553
West Coast	—		7,730		—		—		7,730
Corporate (Intercompany)	(1,220)		(2,955)		(1,450)		(129)		(5,754)
Total	$	126,948	$	64,405	$	59,679	$	2,337	$	253,369

Major Products/service lines
Pumping Equipment	$	86,495	$	—	$	—	$	—	$	86,495
Well Servicing	—		54,132		—		—		54,132
Transport/Vacuum	—		—		36,798		—		36,798
Coiled Tubing	15,179		—		—		—		15,179
RAFT	21,860		—		—		—		21,860

Plugging	—		6,521		—		—		6,521

Production and Disposal Facilities	—		—		6,044		—		6,044
Hot Oiler	—		—		5,003		—		5,003



Other	3,414		3,752		11,834		2,337		21,337
Total	$	126,948	$	64,405	$	59,679	$	2,337	$	253,369

Timing of revenue recognition

Products and services transferred over time	126,948		64,405		59,679		2,337		253,369
Total	$	126,948	$	64,405	$	59,679	$	2,337	$	253,369
Six Months Ended June 30, 2018
Primary Geographical Markets
Permian Basin	$	81,489	$	57,377	$	62,654	$	5,622	$	207,142
Texas Gulf Coast	1,045		14,653		17,488		—		33,186
ArkLaTex & Mid-Continent	105,444		23,950		22,322		—		151,716
Rocky Mountain	56,987		13,135		16,609		—		86,731
Eastern USA	2,957		4,471		—		—		7,428
West Coast	—		14,179		—		—		14,179
Corporate (Intercompany)	(3,377)		(5,823)		(2,885)		(263)		(12,348)
Total	$	244,545	$	121,942	$	116,188	$	5,359	$	488,034

Major Products/service lines
Pumping Equipment	$	159,305	$	—	$	—	$	—	$	159,305
Well Servicing	—		102,668		—		—		102,668
Transport/Vacuum	—		—		72,043		—		72,043
Coiled Tubing	35,159		—		—		—		35,159
RAFT	42,642		—		—		—		42,642

Plugging	—		12,534		—		—		12,534

Production and Disposal Facilities	—		—		11,695		—		11,695
Hot Oiler	—		—		10,388		—		10,388



Other	7,439		6,740		22,062		5,359		41,600
Total	$	244,545	$	121,942	$	116,188	$	5,359	$	488,034

Timing of revenue recognition

Products and services transferred over time	244,545		121,942		116,188		5,359		488,034
Total	$	244,545	$	121,942	$	116,188	$	5,359	$	488,034

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12. Earnings Per Share

The following table sets forth the computation of unaudited basic and diluted loss per share (in thousands, except share data):


	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017

	(Unaudited)				(Unaudited)


Numerator (both basic and diluted):
Net loss	$	(40,054)	$	(23,941)	$	(70,585)	$	(62,567)
Denominator:
Denominator for basic loss per share	26,444,145		26,011,369		26,390,393		26,005,409

Basic loss per common share:	$	(1.51)	$	(0.92)	$	(2.67)	$	(2.41)
Diluted loss per common share:	$	(1.51)	$	(0.92)	$	(2.67)	$	(2.41)

Stock options and warrants of 2,703,326 were excluded from the computation of diluted loss per share for the three and six months ended June 30, 2018 because the effect would have been anti-dilutive. Unvested restricted shares of 21,807 and 12,722 were excluded from the calculation of diluted earnings per share for the three and six months ended June 30, 2018, because the effect would have been anti-dilutive. Unvested stock options and warrants of 1,346,095 and 1,362,232 were excluded from the computation of diluted loss per share for the three and six months ended June 30, 2017, because the effect would have been anti-dilutive.

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13. Business Segment Information

The following table sets forth certain financial information with respect to Basic’s reportable segments (in thousands):


	Completion
	and Remedial		Well		Water		Contract		Corporate
	Services		Servicing		Logistics		Drilling		and Other		Total
Three Months Ended June 30, 2018 (Unaudited)
Operating revenues	$	126,948	$	64,405	$	59,679	$	2,337	$	—	$	253,369
Direct operating costs	(100,528)		(49,680)		(44,008)		(1,743)		—		(195,959)
Segment profits	$	26,420	$	14,725	$	15,671	$	594	$	—	$	57,410
Depreciation and amortization	$	14,815	$	5,890	$	8,038	$	363	$	2,055	$	31,161
Capital expenditures (excluding acquisitions)	$	9,820	$	5,601	$	8,589	$	103	$	322	$	24,435
Three Months Ended June 30, 2017 (Unaudited)
Operating revenues	$	107,385	$	53,054	$	50,740	$	2,117	$	—	$	213,296
Direct operating costs	(81,199)		(41,796)		(41,580)		(1,863)		—		(166,438)
Segment profits	$	26,186	$	11,258	$	9,160	$	254	$	—	$	46,858
Depreciation and amortization	$	12,412	$	4,636	$	6,637	$	501	$	1,770	$	25,956
Capital expenditures (excluding acquisitions)	$	25,849	$	5,116	$	8,916	$	(36)	$	1,004	$	40,849
Six Months Ended June 30, 2018 (Unaudited)
Operating revenues	$	244,545	$	121,942	$	116,188	$	5,359	$	—	$	488,034
Direct operating costs	(190,187)		(97,871)		(84,931)		(4,286)		—		(377,275)
Segment profits	$	54,358	$	24,071	$	31,257	$	1,073	$	—	$	110,759
Depreciation and amortization	$	29,075	$	11,663	$	15,764	$	783	$	4,111	$	61,396
Capital expenditures (excluding acquisitions)	$	21,337	$	12,307	$	10,778	$	510	$	754	$	45,686
Identifiable assets	$	250,249	$	111,043	$	120,814	$	5,899	$	314,229	$	802,234
Six Months Ended June 30, 2017 (Unaudited)
Operating revenues	$	187,817	$	101,672	$	100,946	$	4,880	$	—	$	395,315
Direct operating costs	(148,451)		(82,712)		(83,118)		(4,271)		—		(318,552)
Segment profits	$	39,366	$	18,960	$	17,828	$	609	$	—	$	76,763
Depreciation and amortization	$	24,563	$	9,176	$	13,136	$	991	$	3,503	$	51,369
Capital expenditures (excluding acquisitions)	$	58,058	$	13,493	$	16,337	$	17	$	1,247	$	89,152
Identifiable assets	$	268,381	$	109,817	$	133,557	$	10,025	$	264,586	$	786,366

The following table reconciles the segment profits reported above to the operating loss as reported in the consolidated statements of operations (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017

Segment profits	$	57,410	$	46,858	$	110,759	$	76,763
General and administrative expenses	(51,460)		(36,037)		(92,468)		(70,241)

Depreciation and amortization	(31,161)		(25,956)		(61,396)		(51,369)
Gain (loss) on disposal of assets	(1,921)		223		(3,700)		690

Operating loss	$	(27,132)	$	(14,912)	$	(46,805)	$	(44,157)

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14. Supplemental Schedule of Cash Flow Information

The following table reflects non-cash financing and investing activity during the following periods (in thousands):


	Six Months Ended June 30,
	2018		2017

Capital leases and notes issued for equipment	$	11,047	$	49,214
Asset retirement obligation additions (retirements)	(148)		—
Change in accrued property and equipment	2,942		6,193

Basic paid no income taxes during the six months ended June 30, 2018 and 2017. Basic paid interest of approximately $16.1 million and $9.3 million during the six months ended June 30, 2018 and 2017, respectively.

15. Recent Accounting Pronouncements

ASU 2014-09 - “Revenue from Contracts with Customers (Topic 606)" represents a comprehensive revenue recognition standard to supersede existing revenue recognition guidance and align GAAP more closely with International Financial Reporting Standards (IFRS).

The core principle of the new guidance is that a company should recognize revenue to match the delivery of goods or services to customers to the consideration the company expects to be entitled in exchange for transferring goods or services to a customer. The new standard also requires significantly expanded disclosures regarding the qualitative and quantitative information of revenue and cash flows arising from contracts with customers.

The standard allows for two transition methods: (a) a full retrospective adoption in which the standard is applied to all of the periods presented subject to certain practical expedients, or (b) a modified retrospective adoption in which the standard is applied only to the most current period presented in the financial statements, and which includes additional disclosures regarding the change in accounting principle in the current period. We have adopted the standard effective January 1, 2018 using the modified retrospective method. The adoption of ASU 2014-09 did not have a material impact on the Company’s consolidated financial position, results of operations, equity or cash flows as of the adoption date or for the six months ended June 30, 2018. The Company has included the disclosures required by ASU 2014-09 above.

In February 2016, the FASB issued ASU 2016-02 - “Leases (Topic 842).” The purpose of this update is to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. This update is effective for Basic in annual periods beginning after December 15, 2018, including interim periods within those fiscal years. Basic expects to recognize additional right-of-use assets and liabilities related to operating leases with terms longer than one year. At June 30, 2018, Basic had operating leases with terms longer than one year of $12.4 million.

In November 2016 the FASB issued ASU 2016-18- "Statement of Cash Flows (Topic 230): Restricted Cash," which clarifies the treatment of cash inflows into and cash payments from restricted cash. Restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period amounts shown on the statements of cash flows. The amendments of this ASU should be applied using a retrospective transition method and are effective for reporting periods beginning after December 15, 2017. Basic began presenting cash flows under this standard as of March 31, 2018 and retrospectively for all periods presented. See Note 2, "Cash, Cash Equivalents and Restricted Cash" for disclosures.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Management’s Overview

We provide a wide range of well site services to oil and natural gas drilling and producing companies, including completion and remedial services, well servicing, water logistics and contract drilling.

Our total hydraulic horsepower (“hhp”) decreased to 516,000 at the end of the second quarter of 2018 compared to 518,000 for the second quarter of 2017. Weighted average horsepower increased to 518,000 for the second quarter of 2018 from 488,000 in the second quarter of 2017. Our weighted average number of water logistics trucks decreased to 903 in the second quarter of 2018 from 943 in the second quarter of 2017. Our weighted average number of well servicing rigs decreased to 310 during the second quarter of 2018 compared to 421 in the second quarter of 2017.

Our operating revenues from each of our segments, and their relative percentages of our total revenues, consisted of the following (dollars in millions):


	Six Months Ended June 30,
	2018				2017

Revenues:
Completion and remedial services	$	244.5	50	%	$	187.8	48	%
Well Servicing	121.9		25	%	101.7		26	%
Water Logistics	116.2		24	%	100.9		26	%
Contract drilling	5.4		1	%	4.9		1	%
Total revenues	$	488.0	100	%	$	395.3	100	%

During the fourth quarter of 2015, oil prices declined to levels below $50 per barrel (WTI Cushing) and dropped to levels below $30 in early 2016 before rebounding in late 2016. During 2017 and 2018, oil prices continued to gradually improve with pricing in the low-$70 range by the end of the second quarter of 2018. As a result of the overall increase in pricing, our customers’ activity levels and utilization of our equipment have gradually improved. General improvement in customer confidence has caused the North American onshore drilling rig count to slowly rise, resulting in a sustained increase in completion-related activity during the first half of 2018. Additionally, production related activities, such as well servicing and water logistics, have seen increases in utilization as customers have enhanced their maintenance and workover budgets in 2018.

As a result of gradual improvements in oil pricing and high concentration of equipment and activity, utilization and pricing for our services have remained competitive in our oil-based operating areas. Natural gas prices have been depressed for a prolonged period and utilization and pricing for our services in our natural gas-based operating areas have remained challenged.

We believe that the most important performance measures for our business segments are as follows:

• Completion and Remedial Services — segment profits as a percent of revenues;

• Well Servicing — rig hours, rig utilization rate, revenue per rig hour, profits per rig hour and segment profits as a percent of revenues;

• Water Logistics — trucking hours, revenue per truck, segment profits per truck and segment profits as a percent of revenues; and

• Contract Drilling — rig operating days, revenue per drilling day, profits per drilling day and segment profits as a percent of revenues.

Segment profits are computed as segment operating revenues less direct operating costs. These measurements provide important information to us about the activity and profitability of our lines of business. For a detailed analysis of these indicators for the Company, see “Segment Overview” below.

Selected Acquisitions and Divestitures

During the year ended December 31, 2017 and through the first six months of 2018, we did not enter into or complete any business acquisitions or divestitures.

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Segment Overview

Completion and Remedial Services

During the first six months of 2018, our completion and remedial services segment represented approximately 50% of our revenues. Revenues from our completion and remedial services segment are generally derived from a variety of services designed to complete and stimulate new oil and natural gas production or place cement slurry within the wellbores. Our completion and remedial services segment includes pumping services, rental and fishing tool operations, coiled tubing services, nitrogen services, snubbing and other services.

Our pumping services provide both large and mid-sized fracturing services in selected markets, including vertical and horizontal wellbores. Cementing and acidizing services also are included in our pumping services operations. Our total hydraulic horsepower capacity for our pumping operations was 516,000 at June 30, 2018 and 518,000 at June 30, 2017, respectively. Weighted average horsepower increased to 518,000 for the second quarter of 2018 from 488,000 in the second quarter of 2017.

In this segment, we derive our revenues on a project-by-project basis in a competitive bidding process. Our bids are based on the amount and type of equipment and personnel required, with the materials consumed billed separately. Upon decisions by Saudi Arabia and OPEC to limit production, oil prices and activity increased gradually in the fourth quarter of 2016, and continued to increase gradually throughout 2017. During the first six months of 2018, we had an increase in pricing competition along with a marginal increase in utilization.

The following is an analysis of our completion and remedial services segment for each of the quarters in 2017, the full year ended December 31, 2017 and quarters ended March 31 and June 30, 2018 (dollars in thousands):


	Total	FRAC			Segment
	HHP	HHP	Revenues		Profits %
2017:
First Quarter	443,320	356,900	$	80,431	16	%
Second Quarter	518,365	381,850	$	107,386	24	%
Third Quarter	522,565	413,300	$	123,650	32	%
Fourth Quarter	522,565	413,300	$	121,983	30	%
Full Year	522,565	413,300	$	433,450	27	%
2018:
First Quarter	522,565	413,300	$	117,597	24	%
Second Quarter	516,465	407,800	$	126,948	21	%

The increase in completion and remedial services revenue to $126.9 million in the second quarter of 2018 from $117.6 million in the first quarter of 2018 resulted primarily from weather impact in the first quarter and pricing improvements in our coiled tubing and fracing operations. Segment profits as a percentage of revenue decreased to 21% in the second quarter of 2018 from 24% in first quarter of 2018 due to lower revenues in our coiled tubing service line and increased sand and freight costs in our pressure pumping operations.

Well Servicing

During the first six months of 2018, our well servicing segment represented 25% of our revenues. Revenue in our well servicing segment is derived from completion, production maintenance, workover, manufacturing, and plugging and abandonment services. We provide maintenance-related services as part of the normal, periodic upkeep of producing oil and natural gas wells.

Maintenance-related services represent a relatively consistent component of our business. Workover and completion services generate more revenue per hour than maintenance work due to the use of auxiliary equipment, but demand for workover and completion services fluctuates more with the overall activity level in the industry. We also have a rig manufacturing and servicing facility that builds new workover rigs, performs large-scale refurbishments of used workover rigs and provides maintenance services on previously manufactured rigs.

We charge our well servicing rig customers for services on an hourly basis at rates that are determined by the type of service and equipment required, market conditions in the region in which the rig operates, the ancillary equipment provided on

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the rig and the necessary personnel. Depending on the type of job, we may also charge by the project or by the day. We measure the activity levels of our well servicing rigs on a weekly basis by calculating a rig utilization rate based on a 55-hour work week per rig. Our weighted average number of rigs marketed decreased from 421 in 2017 to 310 at June 30, 2018. We classified 111 rigs from our current fleet as "cold-stacked", reducing our total active rig fleet to 310 rigs, and removed these rigs from the active rig count. These cold-stacked rigs will ultimately be retired and disposed of in an orderly fashion.

The following is an analysis of our well servicing operations for each of the quarters in 2017, the full year ended December 31, 2017 and quarters ended March 31 and June 30, 2018 (dollars in thousands):


	Weighted
	Average		Rig		Revenue
	Number		Utilization		Per Rig		Profits Per
	of Rigs	Rig hours	Rate		Hour		Rig hour		Profits %
2017:
First Quarter	421	157,600	52	%	$	307	$	49	16	%
Second Quarter	421	162,300	54	%	$	321	$	69	21	%
Third Quarter	421	165,200	55	%	$	329	$	69	21	%
Fourth Quarter	421	159,500	53	%	$	339	$	63	19	%
Full Year	421	644,600	54	%	$	324	$	63	19	%
2018:
First Quarter	310	168,500	76	%	$	338	$	55	16	%
Second Quarter	310	181,600	82	%	$	348	$	81	23	%

Rig utilization was 82% in the second quarter of 2018, up from 76% in the first quarter of 2018. The higher utilization rate in the second quarter of 2018 resulted from an increase in well servicing hours caused by increases in customer demand and activity, primarily for our 24-hour rig packages, as well as from seasonal factors. Our segment profit percentage increased to 23% for the second quarter of 2018 compared to 16% in the first quarter of 2018, on increased levels of utilization and continued pricing improvements.

Water Logistics

During the first six months of 2018, our water logistics segment represented approximately 24% of our revenues. Revenues in our water logistics segment are earned from the sale, transportation, treatment, recycling, storage, and disposal of fluids used in the drilling, production and maintenance of oil and natural gas wells. Revenues also include well site construction and maintenance services. The water logistics segment has a base level of business consisting of transporting and disposing of salt water produced as a by-product of the production of oil and natural gas. Water is transported through trucking or via pipeline. Pipelining of water represented approximately 23% of total water disposed in the quarter ended June 30, 2018. These services are necessary for our customers and usually have a stable demand, but produce lower relative segment revenues than other parts of our water logistics segment. Water logistics for completion and workover projects require fresh or brine water for making drilling mud, circulating fluids or frac fluids used during a job, flowback and all of these fluids require storage tanks and hauling and disposal. Because we can provide a full complement of fluid sales, trucking, storage and disposal required on most drilling and workover projects, the add-on services associated with drilling and workover activity generally enable us to generate higher segment profits. The higher segment profits for these add-on services are due to the relatively small incremental labor costs associated with providing these services in addition to our base water logistics segment. Revenues from our water treatment and recycling services include the treatment, recycling and disposal of wastewater, including frac water and flowback, to reuse this water in the completion and production processes. Revenues from our well site construction services are derived primarily from preparing and maintaining well locations, access roads to well locations, and installing small diameter gathering lines and pipelines, constructing foundations to support drilling rigs and providing maintenance services for oil and natural gas facilities. We price water logistics by the job, by the hour, or by the quantities sold, disposed of or hauled.

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The following is an analysis of our water logistics operations for each of the quarters in 2017, the full year ended December 31, 2017 and quarters ended March 31 and June 30, 2018 (dollars in thousands):


	Weighted					Segment
	Average			Revenue		Profits Per
	Number of		Pipeline	Per Water		Water
	Water Logistics	Trucking	Volumes	Logistics		Logistics		Segment
	Trucks	Hours	(in bbls)	Truck		Truck		Profits %
2017:
First Quarter	935	484,300	1,609,000	$	54	$	9	17	%
Second Quarter	943	473,500	1,191,000	$	54	$	10	18	%
Third Quarter	947	483,300	1,560,000	$	55	$	12	21	%
Fourth Quarter	967	492,800	1,921,000	$	57	$	12	20	%
Full Year	948	1,933,900	6,281,000	$	220	$	42	19	%
2018:
First Quarter	960	479,600	1,551,000	$	59	$	16	28	%
Second Quarter	903	486,800	2,064,000	$	66	$	17	26	%

Revenue per water logistics truck increased to $66,000 in the second quarter of 2018 compared to $59,000 in first quarter of 2018 on consistent levels of trucking utilization and construction services revenues. Segment profit percentage decreased to 26% in the second quarter of 2018 from 28% in the first quarter of 2018 primarily due to the weather impacting disposal operations in our Gulf Coast region.

Contract Drilling

During the first six months of 2018, our contract drilling segment represented approximately 1% of our revenues. Revenues from our contract drilling segment are derived primarily from the drilling of new wells.

Within this segment, we charge our drilling rig customers a “daywork” daily rate, or “footage” at an established rate per number of feet drilled. We measure the activity level of our drilling rigs on a weekly basis by calculating a rig utilization rate based on a seven-day work week per rig. Our contract drilling rig fleet had a weighted average of 11 rigs during the second quarter of 2018.

The following is an analysis of our contract drilling segment for each of the quarters in 2017, the full year ended December 31, 2017 and quarters ended March 31 and June 30, 2018 (dollars in thousands):


	Weighted
	Average	Rig
	Number of	Operating	Revenue Per		Profits Per		Segment
	Rigs	Days	Drilling Day		Drilling Day		Profits %
2017:
First Quarter	12	135	$	21	$	2.6	12	%
Second Quarter	11	91	$	23	$	2.8	12	%
Third Quarter	11	92	$	31	$	3.3	11	%
Fourth Quarter	11	139	$	24	$	2.5	11	%
Full Year	11	457	$	24	$	2.8	11	%
2018:
First Quarter	11	175	$	17	$	2.7	16	%
Second Quarter	11	91	$	26	$	6.5	25	%

Revenue per drilling day increased to $25,700 in the second quarter of 2018 compared to $17,300 in the first quarter of 2018. The increase in revenue per drilling day in the second quarter of 2018 was due to an increase in rig trucking revenues. Segment profit percentage increased to 25% in the second quarter of 2018 compared to segment profit of 16% in the first quarter of 2018.

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Operating Cost Overview

Our operating costs are comprised primarily of labor, including workers’ compensation and health insurance, repair and maintenance, fuel and insurance. The majority of our employees are paid on an hourly basis. We also incur costs to employ personnel to sell and supervise our services and perform maintenance on our fleet. These costs, however, are not directly tied to our level of business activity. Repair and maintenance is performed by our crews, company maintenance personnel and outside service providers. Compensation for our administrative personnel in local operating yards and in our corporate office is accounted for as general and administrative expenses. Insurance is generally a fixed cost regardless of utilization and relates to the number of rigs, trucks and other equipment in our fleet, employee payroll and safety record.

Critical Accounting Policies and Estimates

Our unaudited consolidated financial statements are impacted by the accounting policies used and the estimates and assumptions made by management during their preparation. A complete summary of our significant accounting policies is included in Note 3. Summary of Significant Accounting Policies of the Financial Statements and Supplementary Data in our most recent Annual Report on Form 10-K.

Results of Operations

The following is a comparison of our results of operations for the three and six months ended June 30, 2018 compared to the three and six months ended June 30, 2017. For additional segment-related information and trends, please read “Segment Overview” above.

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

Revenues. Revenues increased by 19% to $253.4 million during the second quarter of 2018 from $213.3 million during the same period in 2017. This increase was primarily due to increased demand for our services by our customers, particularly completion and remedial services, compared to the same period in 2017, when our customers were working with reduced capital budgets. After a prolonged period of lower oil prices, our customers have gradually increased their capital and operating spending levels.

Completion and remedial services revenues increased by 18% to $126.9 million during the second quarter of 2018 compared to $107.4 million in the same period in 2017. The increase in revenue between these periods was primarily due to improved demand for completion related activities and slightly improved pricing for our services, particularly in our pumping services and coiled tubing lines of business. Total hydraulic horsepower decreased to 516,000 at June 30, 2018 from 518,000 at June 30, 2017. Weighted average horsepower increased to 518,000 for the second quarter of 2018 from 488,000 in the second quarter of 2017.

Well servicing revenues increased by 21% to $64.4 million during the second quarter of 2018 compared to $53.1 million during the same period in 2017. The increase was driven by an increase in utilization of our equipment, primarily due to increases in customer demand. Our weighted average number of well servicing rigs decreased to 310 during the second quarter of 2018 compared to 421 in the first quarter of 2017. Utilization increased to 82% in the second quarter of 2018, compared to 54% (71% based on our current fleet of 310 rigs) in the comparable quarter of 2017 due to decreased rig count and higher rig hours. Revenue per rig hour in the second quarter of 2018 was $348, increasing from $321 in the comparable quarter of 2017 due to rate increases to customers.

Water logistics revenues increased by 18% to $59.7 million during the second quarter of 2018 compared to $50.7 million in the same period in 2017. Our revenue per water logistics truck increased 22% to $66,000 in the second quarter of 2018 compared to $54,000 in the same period in 2017 mainly due to increases in pipelining, trucking activity and pricing. Pipeline water volumes increased to 2.0 million barrels or 23% of total disposal volumes compared to 1.2 million barrels or 14% of total disposal volumes in the second quarter of 2017. Our weighted average number of water logistics trucks decreased to 903 during the second quarter of 2018 compared to 943 in the same period in 2017.

Contract drilling revenues increased by 10% to $2.3 million during the second quarter of 2018 compared to $2.1 million in the same period in 2017. The number of rig operating days remained constant at 91 in the second quarter of 2018 and 2017. The increase in revenue was due to increases in pricing and trucking activity in the Permian Basin.

Direct Operating Expenses. Direct operating expenses, which primarily consist of labor, including workers’ compensation and health insurance, repair and maintenance, fuel and insurance, increased to $196.0 million during the second quarter of 2018 from $166.4 million in the same period in 2017, primarily due to increases in activity and corresponding increases in employee headcount and wages to adapt to current activity levels.

Direct operating expenses for the completion and remedial services segment increased by 24% to $100.5 million during the second quarter of 2018 compared to $81.2 million for the same period in 2017 due primarily to increased activity levels overall,

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especially in our pumping and coil tubing services. Segment profits decreased to 21% of revenues during the second quarter of 2018 compared to 24% for the same period in 2017, due to competitive pricing pressures.

Direct operating expenses for the well servicing segment increased by 19% to $49.7 million during the second quarter of 2018 compared to $41.8 million for the same period in 2017. The increase in direct operating expenses corresponds to increased workover and plugging activity levels. Segment profits increased to 23% of revenues during the second quarter of 2018 from 21% for the same period in 2017 due to incremental margins from a higher revenue base.

Direct operating expenses for the water logistics segment increased by 6% to $44.0 million during the second quarter of 2018 compared to $41.6 million for the same period in 2017. Segment profits were 26% of revenues during the second quarter of 2018 compared to 18% for the same period in 2017, due to incremental margins from a higher revenue base.

Direct operating expenses for the contract drilling segment decreased 6% to $1.7 million during the second quarter of 2018 compared to $1.9 million for the same period in 2017, due to increased wages. Segment profits increased to 25% of revenues during the second quarter of 2018 from a segment profit of 12% during the second quarter of 2017 due to an increase in pricing.

General and Administrative Expenses. General and administrative expenses increased by 43% to $51.5 million during the second quarter of 2018 from $36.0 million for the same period in 2017. The increase was partially due to stock-based compensation expense, which was $9.6 million, including $3.9 million related to retirement of an executive officer, and $6.3 million during the second quarter of 2018 and 2017, respectively. In addition, we incurred certain costs, including our Texas sales and use tax audit liability totaling $6.0 million, bad debt related to a single customer of $3.1 million, and accrued consulting fees related to our strategic realignment of approximately $2.0 million in the second quarter of 2018.

Depreciation and Amortization Expenses. Depreciation and amortization expenses were $31.2 million during the second quarter of 2018 compared to $26.0 million for the same period in 2017.

Interest Expense. Interest expense increased to $12.8 million during the second quarter of 2018 compared to $9.2 million during the second quarter of 2017. Interest expense increases were related to interest on our New ABL Facility which was entered into in the third quarter of 2017, accrued interest of $1.5 million related to the Texas sales and use tax audit and additional capital leases.

Income Tax Expense. There was an income tax expense of $0.3 million during the second quarter of 2018 compared to an income tax expense of $0 for the same period in 2017. Excluding the impact of the valuation allowance, our effective tax rate during the second quarter of 2018 and 2017 was approximately 20% and 36%, respectively.

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

Revenues. Revenues increased by 23% to $488.0 million during the six months ended June 30, 2018 from $395.3 million during the same period in 2017. This increase was primarily due to increased demand for our services by our customers, particularly completion and remedial services, compared to the same period in 2017, when our customers were working with reduced capital budgets. After a prolonged period of lower oil prices, our customers have gradually increased their capital and operating spending levels.

Completion and remedial services revenues increased by 30% to $244.5 million during the six months ended June 30, 2018 compared to $187.8 million in the same period in 2017. The increase in revenue between these periods was primarily due to improved demand for completion related activities and slightly improved pricing for our services, particularly in our pumping services and coiled tubing lines of business. Total hydraulic horsepower decreased to 516,000 at June 30, 2018 from 518,000 at June 30, 2017. Weighted average horsepower increased to 518,000 for the six months ended June 30, 2018 from 488,000 for the six months ended June 30, 2017.

Well servicing revenues increased by 20% to $121.9 million during the six months ended June 30, 2018 compared to $101.7 million during the same period in 2017. The increase was driven by an increase in utilization of our equipment and increased customer demand, particularly increased demand for our 24-hour rig packages. Our weighted average number of well servicing rigs decreased to 310 during the six months ended June 30, 2018 compared to 421 in the six months ended June 30, 2017. Utilization increased to 79% in the six months ended June 30, 2018, compared to 53% (71% based on our current fleet of 310 rigs) in the comparable period of 2017 due to decreased rig count and higher rig hours. Revenue per rig hour in the six months ended June 30, 2018 was $343, increasing from $314 in the comparable period of 2017 due to rate increases to customers.

Water logistics revenues increased by 15% to $116.2 million during the six months ended June 30, 2018 compared to $100.9 million in the same period in 2017. Our revenue per water logistics truck increased 16% to $125,000 in the six months ended June 30, 2018 compared to $108,000 in the same period in 2017 mainly due to increases in pipelining, trucking activity and pricing. For the six months ended June 30, 2018 pipeline water volumes increased to 3.6 million barrels or 21% of total disposal volumes compared to 2.8 million barrels or 17% of total disposal volumes for the six months ended June 30, 2017. Our weighted average number of water logistics trucks decreased to 928 during the six months ended June 30, 2018 compared to

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939 in the same period in 2017.

Contract drilling revenues increased by 10% to $5.4 million during the six months ended June 30, 2018 compared to $4.9 million in the same period in 2017. The number of rig operating days increased by 18% to 266 in the six months ended June 30, 2018 compared to 226 in the same period in 2017. The increase in revenue was due to an increase in drilling activity in the Permian Basin.

Direct Operating Expenses. Direct operating expenses, which primarily consist of labor, including workers’ compensation and health insurance, repair and maintenance, fuel and insurance, increased to $377.3 million during the six months ended June 30, 2018 from $318.6 million in the same period in 2017, primarily due to increases in activity and corresponding increases in employee headcount and wages to adapt to current activity levels.

Direct operating expenses for the completion and remedial services segment increased by 28% to $190.2 million during the six months ended June 30, 2018 compared to $148.5 million for the same period in 2017 due primarily to increased activity levels overall, especially in our pumping and coiled tubing services. Segment profits increased to 22% of revenues during the six months ended June 30, 2018 compared to 21% for the same period in 2017, due to the improved utilization of equipment, price increases and incremental margins from a higher revenue base.

Direct operating expenses for the well servicing segment increased by 18% to $97.9 million during the six months ended June 30, 2018 compared to $82.7 million for the same period in 2017. The increase in direct operating expenses correspond to increased workover and plugging activity levels. Segment profits increased to 20% of revenues during the six months ended June 30, 2018 compared to 19% for the same period in 2017.

Direct operating expenses for the water logistics segment increased by 2% to $84.9 million during the six months ended June 30, 2018 compared to $83.1 million for the same period in 2017. Segment profits were 27% of revenues during the six months ended June 30, 2018 compared to 18% for the same period in 2017, due to incremental margins from a higher revenue base.

Direct operating expenses for the contract drilling segment remained constant at $4.3 million during the six months ended June 30, 2018 and 2017. Segment profits increased to 20% of revenues during the six months ended June 30, 2018 from a segment profit of 12% during the six months ended June 30, 2017 due to an increase in pricing.

General and Administrative Expenses. General and administrative expenses increased by 32% to $92.5 million during the six months ended June 30, 2018 from $70.2 million for the same period in 2017. The increase was partially due to stock-based compensation expense, which was $16.4 million, including $3.9 million related to retirement of an executive officer, and $10.7 million during the six months ended June 30, 2018 and 2017, respectively. In addition, we incurred costs related our Texas Sales and Use Tax audit liability totaling $6.0 million, bad debt related to a single customer of $3.1 million, accrued consulting fees related to our strategic realignment of approximately $2.0 million in the first half of 2018, costs associated with a withdrawn bond offering resulted in $1.8 million of legal and professional fees expense, and accrual costs related to annual executive bonuses approved by the Compensation Committee of the Board in the first half of 2018 were $1.7 million.

Depreciation and Amortization Expenses. Depreciation and amortization expenses were $61.4 million during the six months ended June 30, 2018 compared to $51.4 million for the same period in 2017 due to capital additions.

Interest Expense. Interest expense increased to $24.1 million during the six months ended June 30, 2018 compared to $18.3 million during the six months ended June 30, 2017. Interest expense increases were related to interest on our New ABL Facility which was entered into in the third quarter of 2017, accrued interest of $1.5 million related to the Texas sales and use tax audit and additional capital leases.

Income Tax Expense. There was an income tax expense of $0.2 million during the six months ended June 30, 2018 compared to an income tax expense of $0.4 million for the same period in 2017. Excluding the impact of the valuation allowance, our effective tax rate during the six months ended June 30, 2018 and 2017 was approximately 19% and 36%, respectively.

Liquidity and Capital Resources

As of June 30, 2018, our primary capital resources were net cash provided by operations, utilization of capital leases and borrowings under our $150.0 million New ABL Facility. As of June 30, 2018, we had unrestricted cash and cash equivalents of $30.7 million compared to $38.5 million as of December 31, 2017. An additional amount of $47.1 million is classified as restricted cash to collateralize insurance reserves. Including availability of $14.7 million under our New ABL Facility, we had total liquidity of $45.4 million as of June 30, 2018. On April 11, 2018, the Company entered into Amendment No. 2 (“Amendment No. 2”) to the New ABL Facility. Among other things, Amendment No. 2 (i) increased the aggregate commitments under the Credit Agreement from $120 million to $150 million, (ii) added Morgan Stanley Senior Funding, Inc. as a lender and amended the commitment schedule to the Credit Agreement to reflect the same. As of June 30, 2018, Basic was

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in compliance with all debt covenants, as waived. In the second quarter, Basic received a waiver with our Term Loan lenders to increase our maximum capital expenditures to $35 million from $30.0 million and lower required cash balance from $25.0 million to $20.0 million for the quarter.

We have utilized, and expect to utilize in the future, bank and capital lease financing and sales of equity to obtain capital resources. When appropriate, we will consider public or private debt and equity offerings and non-recourse transactions to meet our liquidity needs.

Net Cash Provided by Operating Activities

Cash provided by operating activities was $25.1 million for the six months ended June 30, 2018, an increase compared to cash used in operating activities of $13.4 million during the same period in 2017. Operating cash flow provided in the first six months of 2018 improved compared to cash used in the same period in 2017 due to stronger operating results and improved working capital levels due to better accounts receivable collections.

Our liquidity, including our ability to meet our ongoing operational obligations, is dependent upon, among other things, our ability to maintain adequate cash on hand and generate cash flow from operations. Maintaining adequate liquidity depends upon industry conditions and financial, competitive, and other factors beyond our control. In the event that cash on hand and cash flow from operations is not sufficient to meet our liquidity needs, we may have limited access to additional financing.

Capital Expenditures

Cash capital expenditures during the first six months of 2018 were $31.7 million with an additional $2.9 million of accrued capital expenditures compared to $33.7 million in the same period of 2017. We added $11.0 million of leased assets through our capital lease program and other financing arrangements during the first six months of 2018 compared to $49.2 million of leased asset additions in the same period in 2017.

We currently have planned capital expenditures for the full year of 2018 of under $80.0 million, including capital leases of $20.0 million. We do not budget acquisitions in the normal course of business, and we regularly engage in discussions related to potential acquisitions related to the oilfield services industry.

Capital Resources and Financing

Our current primary capital resources are cash flow from our operations, our New ABL Facility, the ability to enter into capital leases, and a cash balance of $30.7 million at June 30, 2018. We had $90.0 million of borrowings under the New ABL Facility as of June 30, 2018, of which $47.1 million of cash is held in restricted cash as collateral for letters of credit, giving us approximately $14.7 million of available borrowing capacity subject to covenant constraints under our New ABL Facility. In 2018, we financed activities in excess of cash flow from operations primarily through the use of cash, capital leases and other financing arrangements. Our Amended and Restated Term Loan Agreement (the "Term Loan Agreement") had $161.7 million aggregate outstanding principal amount of loans as of June 30, 2018 and no additional borrowing capacity.

Contractual Obligations

We have significant contractual obligations in the future that will require capital resources. Our primary contractual obligations are (1) our capital leases, (2) our operating leases, (3) our asset retirement obligations and (4) our other long-term liabilities. The following table outlines our contractual obligations as of June 30, 2018 (in thousands):


	Obligations Due in
	Periods Ended June 30,
Contractual Obligations	Total		2018		2019 to 2020		2021 to 2022		Thereafter
Term Loan Agreement	$	161,700	$	825	$	3,300	$	157,575	$	—
New ABL Facility	90,000		—		—		90,000		—
Capital leases and other financing arrangements	85,347		31,660		43,791		9,826		70
Operating leases	14,981		2,567		7,267		4,989		158
Asset retirement obligation	2,437		656		665		227		889
Total	$	354,465	$	35,708	$	55,023	$	262,617	$	1,117

Interest on long-term debt relates to our future contractual interest obligations under the Term Loan Agreement, the New ABL Facility and our capital leases. Our capital leases relate primarily to light-duty and heavy-duty vehicles and trailers. Our operating leases relate primarily to real estate. Our asset retirement obligation relates to disposal wells.

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Our ability to access additional sources of financing will be dependent on our operating cash flows and demand for our services, which could be negatively impacted due to the extreme volatility of commodity prices.

Other Matters

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that is material to investors.

Net Operating Losses

As of June 30, 2018, Basic had approximately $732.2 million of net operating loss carryforwards ("NOL"), for federal income tax purposes, which begin to expire in 2031 and $265.9 million of NOLs for state income tax purposes which begin to expire in 2018. Net operating losses generated after 2017 are carried forward indefinitely and are limited to 80% of taxable income. Net operating losses generated prior to 2018 continue to be carried forward for 20 years and have no 80% limitation on utilization.

Basic provides a valuation allowance when it is more likely than not that some portion of the deferred tax assets will not be realized. As of June 30, 2018, a valuation allowance of $159.9 million was recorded against the Company's net deferred tax assets for all jurisdictions that are not expected to be realized.

Recent Accounting Pronouncements

The Company's consideration of recent accounting pronouncements is included in Note 15. Recent Accounting Pronouncements to the consolidated financial statements included in this quarterly report.

Impact of Inflation on Operations

Management is of the opinion that inflation has not had a significant impact on our business.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As of June 30, 2018, we had no material changes to the disclosure on this matter made in our Annual Report on Form 10-K for the year ended December 31, 2017.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

As required by Rule 13a-15(b) of the Exchange Act, we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this Form 10-Q. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file or submit under the Exchange Act 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 and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based upon the evaluation, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were effective as of June 30, 2018, at the reasonable assurance level.

Changes in Internal Control Over Financial Reporting

During the most recent fiscal quarter, there have been no changes in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II — OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

From time to time, we are a party to litigation or other legal proceedings that we consider to be a part of the ordinary course of business. We are not currently involved in any legal proceedings that we consider probable or reasonably possible,

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individually or in the aggregate, to result in a material adverse effect on our financial condition, results of operations or liquidity.

ITEM 1A. RISK FACTORS

During the quarter ended June 30, 2018, there have been no material changes in our risk factors disclosed in Part I Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2017, except for the following:

We may not be successful in implementing and maintaining technology development and enhancements. New technology may cause us to become less competitive.

The oilfield services industry is subject to the introduction of new drilling and completion techniques and services using new technologies, some of which may be subject to patent protection. Our competitors may develop or acquire the right to use new technologies not available to us, which may place us at a competitive disadvantage. In addition, we may face competitive pressure to implement or acquire new technologies at a substantial cost. Some of our competitors have greater resources that may allow them to implement new technologies before we can. Our inability to develop and implement new technologies or products on a timely basis and at competitive cost could have a material adverse effect on our financial position and results of operations.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

There were no repurchases of equity securities during the period.

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ITEM 6. EXHIBITS


Exhibit
No.						Description

2.1*						First Amended Joint Prepackaged Chapter 11 Plan of Basic Energy Services, Inc. and its Affiliated Debtors, dated December 7, 2016 (Incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-32693), filed on December 12, 2016).
2.2*						Findings of Fact, Conclusions of Law, and Order Approving the Debtors’ Joint Prepackaged Chapter 11 Plan of Basic Energy Services, Inc. and its Affiliated Debtors, dated December 9, 2016 (Incorporated by reference to Exhibit 99.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-32693) filed on December 12, 2016).
3.1*						Second Amended and Restated Certificate of Incorporation of Basic Energy Services, Inc. (Incorporated by reference to Exhibit 3.1 to the Company’s Registration Statement on Form 8-A12B (SEC File No. 001-32693) filed on December 23, 2016).
3.2*						Second Amended and Restated Bylaws of Basic Energy Services, Inc. (Incorporated by reference to Exhibit 3.2 to the Company’s Registration Statement on Form 8-A12B (SEC File No. 001-32693) filed on December 23, 2016).



4.1*						Specimen Stock Certificate representing Common Stock of the Company (Incorporated by reference to Exhibit 4.1 of the Company’s Registration Statement on Form 8-A12B (SEC File No. 001-32693), filed on December 23, 2016).
4.2*						Warrant Agreement between Basic, as issuer, and American Stock Transfer & Trust Company, LLC, as warrant agent, dated as of December 23, 2016. (Incorporated by reference to Exhibit 4.1 to Form 8-A12G (SEC File No. 001-32693) filed on December 23, 2016).
4.3*						Registration Rights Agreement, dated as of December 23, 2016, between Basic and certain stockholders (Incorporated by reference to Exhibit 10.1 of the Company’s Registration Statement on Form 8-A12B (SEC File No. 001-32693) filed on December 23, 2016).
10.1*						Transition Services Agreement, dated April 3, 2018, between Basic and Alan Krenek Form of Performance-Based Stock Unit Award Agreement (Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-32693) filed on February 14April 3, 2018).
10.2*						Amendment No. 2 to the Credit and Security Agreement, dated April 11, 2018 (Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-32693) filed on April 17, 2018).
31.1#						Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act.
31.2#						Certification by Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act.
32.1##						Certification of Chief Executive Officer pursuant to 18 U.S.C Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2##						Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.CAL#						XBRL Calculation Linkbase Document
101.DEF#						XBRL Definition Linkbase Document
101.INS#						XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.LAB#						XBRL Labels Linkbase Document
101.PRE#						XBRL Presentation Linkbase Document
101.SCH#						XBRL Schema Document

*Incorporated by reference

#Filed with this report

##Furnished with this report

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SIGNATURES

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




BASIC ENERGY SERVICES, INC.

By:			/s/ T.M. "Roe" Patterson
Name:			T. M. “Roe” Patterson
Title:			President, Chief Executive Officer and
			Director (Principal Executive Officer)

By:			/s/ Alan Krenek
Name:			Alan Krenek
Title:			Senior Vice President, Chief Financial Officer, Treasurer
			and Secretary (Principal Financial Officer and
			Principal Accounting Officer)

Date: August 2, 2018